Banning City Council
May 12, 2026

May 12, 2026
4:00 p.m.

In Chambers
Council Chambers
99 E. Ramsey Street
Banning, CA 92220

1. CALL TO ORDER

2. WORKSHOP

2.1 Parks and Recreation Commission Interviews for Position 1

2.2 Discussion of the City of Banning Electric Utility's Electric System Master Plan

3. PUBLIC COMMENTS - Agenda Items Only
AGENDA

CITY COUNCIL - SPECIAL MEETING (WORKSHOP)

CITY OF BANNING, CALIFORNIA
The following information comprises the agenda for the special meeting of the Banning City Council, a joint meeting of the City Council and Banning Utility Authority, and the Banning City Council sitting in its capacity as the Banning Successor Agency Board.

This meeting is being held via Zoom so that members of the public may observe and participate in this meeting electronically. If you participate in this meeting via Zoom, you are agreeing to abide by the City's Zoom Community Standards for Public Meetings (provided in full on the last page of the agenda). Esta reunión se lleva a cabo en la Cámara y a través de Video/Teleconferencia en Zoom para que los miembros del público puedan observar y participar en esta reunión de manera electrónica. Si elige participar en esta reunión a través de Zoom, acepta cumplir con los Estándares comunitarios de Zoom para reuniones públicas de la ciudad (que se proporcionan en su totalidad en la última página de la agenda).

To observe and participate in the online video portion of the meeting through your personal computer or device, follow this link:
https://us02web.zoom.us/j/82012644588?pwd=GwdLNir0X6fHkhlgVjAjRUQf1C6yoz.1 Dial in: +1 669 900 9128
Meeting ID: 820 1264 4588
Password: 1913-92220
Per the City of Banning Manual of Procedural Guidelines, matters taken up by the Council before 10 p.m. may be concluded, but no new matters shall be taken up except upon a majority vote of the council members present and voting. Such an extension shall only be valid for one hour and each hour thereafter shall require a renewed action for the meeting to continue.

Recommendation: Conduct interviews to fill Parks and Recreation Commission vacancy for Position 1, term ending January 31, 2029.

Recommendation: Receive the presentation regarding the Electric System Master Plan City Council - Special Meeting (Workshop) Agenda
May 12, 2026
1 4. ADJOURNMENT
Zoom Community Standards for Public Meetings
By participating in this meeting on Zoom, you are agreeing to abide by the City of Banning’s Community Standards for Public Meetings. Zoom attendees that fail to adhere to these standards may be removed from the meeting room.

Your microphone must remain on mute, and you may only unmute your microphone when/if you are recognized by the Mayor.

Your camera must be turned off unless/until you are recognized by the Mayor.

To indicate a desire to make Public Comment, you must use the Raise Hand function. The Mayor will not recognize those who have not used the Raise Hand function.

Public Comment from Zoom attendees will immediately follow in-person comment from members of the public in Council Chambers.

If you fail to adhere to these community guidelines, you may be removed for disrupting the meeting occurring in Council Chambers. You may rejoin the meeting but may be removed for each violation of these community standards.

The chat function will be disabled for all City Council meetings on Zoom.

Estándares comunitarios de Zoom para Reuniones Públicas Al participar en esta reunión en Zoom, usted acepta cumplir con los Estándares Comunitarios para Reuniones Públicas de la ciudad de Banning. Los que atienden por Zoom que no cumplan con estos estándares pueden ser retirados de la sala de reuniones.

Su micrófono debe permanecer en silencio, y solo puede reactivar su micrófono cuando / si es reconocido por el alcalde.

Su cámara debe estar apagada a menos que sea reconocido por el alcalde.

Para indicar el deseo de hacer un Comentario Público, debe utilizar la función Levantar la mano. El alcalde no reconocerá a quienes no hayan utilizado la función Levantar la mano.

Los comentarios públicos de lo que atienden por Zoom seguirán inmediatamente los comentarios en persona de los miembros del público en las Cámaras del Consejo.

Si no cumple con estas pautas de la comunidad, es posible que lo destituyan por interrumpir la reunión que tiene lugar en las Cámaras del Consejo. Puede volver a unirse a la reunión, pero es posible que lo eliminen por cada violación de estos estándares de la comunidad.

La función de chat estará deshabilitada para todas las Reuniones del Ayuntamiento en Zoom.

AFFIDAVIT • DECLARACIÓN JURADA
IT IS HEREBY CERTIFIED under the laws of the State of California that the above agenda was posted on the City's website (www.banningca.gov) as well as the Bulletin Board at Banning City Hall, located at 99 E Ramsey Street, Banning, CA 92220, at least 24 hours in advance of the meeting.
_________________________
Vickie Sellers, Elected City Clerk
Secretaria Municipal Electa
City Council - Special Meeting (Workshop) Agenda
May 12, 2026
2 PUBLIC NOTICE • NOTICIA PÚBLICA
Meeting Agendas and Notices
Interested in receiving email and/or text notifications of upcoming City Council meetings? Sign up for meeting notifications through the City's website. Pursuant to amended Government Code §54957.5(b), staff reports and other public records related to open session agenda items are available on the City's website (www.banningca.gov/).

Public Comment
Agenda Items
Any member of the public may address this meeting of the City Council on any item appearing on the agenda. A five-minute limitation shall apply to each member of the public and no member of the public shall be permitted to share their time with any other person.

Non-Agenda Items
Any member of the public may address this meeting of the City Council on any item which does not appear on the regular meeting agenda but is of interest to the general public and is an item upon which the City Council may act. A three-minute limitation shall apply to each member of the public and no member shall be permitted to share their time with any other person. No action shall be taken, nor discussion held by the City Council, on any item which does not appear on the agenda, unless the action is otherwise authorized in accordance with the provisions of subdivision (b) of §54954.2 of the Government Code.

Special Assistance/Accessibility Requests
In compliance with the Americans with Disabilities Act, any member of the public may request that the agenda and agenda packet be mailed to them. If you need special assistance to participate in this meeting (such as translation services), please contact the City Clerk's Office. Advanced notification of at least 48 hours prior to the meeting will allow the city to make arrangements to ensure your accessibility.
¿Necesita servicios de traducción para participar? Contacto Oficina del Secretario de la Ciudad.

CONTACT • CONTACTO
City Clerk's Office | 951-922-3102 | [email protected] 99 East Ramsey Street, Banning, California 92220
City Council - Special Meeting (Workshop) Agenda
May 12, 2026
3 CITY OF BANNING

STAFF REPORT
TO: CITY COUNCIL
FROM: Elizabeth Gibbs, City Manager
PREPARED BY: Sandra Calderon, Deputy City Clerk
MEETING DATE: May 12, 2026
SUBJECT: Parks and Recreation Commission Interviews for Position 1 RECOMMENDATION:

Conduct interviews to fill Parks and Recreation Commission vacancy for Position 1, term ending January 31, 2029.

BACKGROUND:

The Parks and Recreation Commission’s rules and responsibilities are governed by Chapter 2.40 of the Municipal Code. The Commission’s main function is to serve as an advisory board to the City Council and the Parks and Recreation Director for the purpose of the formulation of rules, regulations and policies for all parks and recreation programs, activities, and fees.

The Banning Municipal Code Section 2.40.030 requires applications be made available and vacancies announced at least two months prior to the vacancy. The Parks and Recreation vacancy was advertised on the City's website and across social media platforms starting on March 25, 2026. Public Notice was published in the Record Gazette on March 27, 2026. The deadline to submit an application was Thursday, April 30, 2026.

JUSTIFICATION:

Two applications were received for the Parks and Recreation Commission vacancy and are up for consideration:

Monette Hamilton
Cheryce Cobbs
Staff recommend asking the applicant the following question:

1. Tell us briefly about yourself (qualities/experience/expertise) and why you are interested on being on the City’s Parks & Recreation Commission.

2. Explain your knowledge of the Parks & Recreation Commission’s roles and responsibilities for City services and how it contributes to creating a quality of life for the residents and people who visit the community.

FISCAL IMPACT:

N/A
ATTACHMENTS:

1. Monette Hamilton_Application_Redacted.pdf
4 2. Cheryce Cobbs_Application_Redacted.pdf

3. Banning__CA_Code_of_Ordinances_2.40.pdf

4. Parks & Rec_Proof of Publication.pdf
5 6
7 8
9 A.

B.

C.

D.

A.

B.

C.

Chapter 2.40 - PARKS AND RECREATION COMMISSION

2.40.010 - Established—Purpose.

There is hereby established a parks and recreation commission of the city for the purpose of facilitating the integration of the parks and recreation activities for the city. (Code 1965, § 15-1; Ord. No. 1438, § 1.A., 6-14-11)

2.40.020 - Advisory agency designated—Powers and duties.

The city parks and recreation commission shall serve as an advisory agency to the city council and the director of community services for the purpose of the formulation of rules, regulations and policies for all parks and recreation programs, activities, and fees. Parks and recreation commission members shall be registered voters of the City of Banning.
(Code 1965, § 15-2; Ord. No. 1438, § 1.A., 6-14-11)

2.40.030 - Appointment of members.

The parks and recreation commission shall consist of five members.

The parks and recreation commission shall serve four-year terms, which shall be staggered every two years concurrent with the city elections. Appointments shall be made by the city council.

Applications shall be made available and the closing date announced at least two months prior to the expiration of the commissioner's term to be filled.

Members shall serve at the pleasure of the council and may be removed at any time by a majority vote of the entire council.

Any member who is absent from two regular meetings of the Commission within a twelve-month period whether the absence is excused or not, will be deemed to have resigned their office and the City Council may appoint a new member to serve in the resigned commissioner's place for the remainder of the existing term.
(Code 1965, § 15-3; Ord. No. 1438, § 1.A., B., 6-14-11; Ord. No. 1579, § 2, 11-9-21)

2.40.040 - Conduct of meetings.

The commission shall meet at 6:00 P.M. on the third Wednesday of the following months: January, February, March, April, May, June, September, October and November.

Additional meeting may occur if deemed necessary by the city council or commission chairperson.

A majority of the voting members of the commission shall constitute a quorum. 10 (Code 1965, § 15-4; Ord. No. 1438, § 1.A., 6-14-11)
11 FILER

SANDRA CALDERON
[email protected]
(951) 922-3125

FILING FOR
Record Gazette

OFFICIAL AD PROOF
This is the proof of your ad scheduled to run in Record Gazette on the dates indicated below. If changes are needed, please contact us prior to deadline at (951) 849-4586.

Notice ID: yl5yIuVT5WEhReX5YsBP | Proof Updated: Mar. 25, 2026 at 11:54am PDT Notice Name: City of Banning Public Notices PRC Vacancy This is not an invoice. Below is an estimated price, and it is subject to change. You will receive an invoice with the final price upon invoice creation by the publisher.

Columns Wide: 1
Total Column Inches: 1.25
Number of Lines: n/a
Ad Class: Legals
03/27/2026: Display Ad Notice 265.72
Subtotal $265.72
Tax $0.00
Processing Fee $0.00
Total $265.72
See Proof on Next Page
City of Banning Public Notices PRC Vacancy - Page 1 of 2 12 Expected print dimensions of advertisement: Newspaper page size: Width: 9.75 in., Height: 10.88 in.

Width: 1.25 in., Height: 1.25 in. Publisher may wrap or break notice between pages.

City of Banning Public Notices PRC Vacancy - Page 2 of 2 13 CITY OF BANNING

STAFF REPORT
TO: CITY COUNCIL
FROM: Elizabeth Gibbs, City Manager
PREPARED BY: Fred Lyn, Deputy Director of Electric
Art Vela, Director of Public Works
MEETING DATE: May 12, 2026
SUBJECT: Discussion of the City of Banning Electric Utility's Electric System Master Plan
RECOMMENDATION:

Receive the presentation regarding the Electric System Master Plan BACKGROUND:

The purpose of this workshop is to provide the City Council with an overview of the recently completed Electric System Master Plan ("ESMP") by Finley Engineering Company. The ESMP provides a high-level guide for planning, operating, and maintaining the electric distribution system for the Banning Electric Utility (BEU) over the next two decades. The plan also identifies the long-term outlook of the electric utility, assesses its current conditions, and provides both a 5-year and a 15-year long-term capital improvement plan to address current and future challenges all designed to increase reliability, safety, and address future load growth. The long-term approach of the 20-year timeline will allow BEU to plan how to address these issues in a way as to allow for flexibility in budget while concurrently maintaining reliability in a steady fashion.

JUSTIFICATION:

The City of Banning Electric Utility's (BEU’s) overall electricity consumption has increased by approximately 10 percent over the past three years, and the City must ensure that BEU’s electric transmission and distribution facilities are adequate in order to accommodate future load growth and address aging infrastructure.

The ESMP is a blueprint guide for planning, operating and maintaining BEU for the next 20 years. The ESMP consists of the following:
an initial system assessment;
review of BEU's practices and performance;
regulatory impacts;
condition of the electric infrastructure;
system distribution modeling and planning criteria;
performing a load forecast that considered multiple growth cases; a load flow analysis of the electric system in regards to overall system voltage profile and reliability;
development of a capital improvement plan to address findings of the assessments and analysis, and addressing aging infrastructure
FISCAL IMPACT:
14 There is no immediate fiscal impact associated with this workshop.

ATTACHMENTS:

1. City of Banning Electric System Master Plan
15 CITY OF BANNING, CALIFORNIA
2026-2045 ELECTRIC SERVICE MASTER PLAN
APRIL 2026
Prepared by:

Finley Engineering Company, Inc.

On behalf of:

Banning Electric Utility
Contact Information:

Finley Engineering Company, Inc.

PO Box 148, 104 E. 11th Street
Lamar, MO 64795
(417) 682-5531
www.finleyusa.com
City of Banning
99 E. Ramsey Street
Banning, CA 92220
951.922.3100
www.banningca.gov
16016

ENGINEERS CERTIFICATION
I, Christopher Adam Smart, P.E., herby certify that this 2026-2045 Electric Service Master Plan was prepared by me or under my direct Supervision and that I am a duly Licensed Professional Engineer under the laws of the state of California, license number E 25395.

X
16117

TABLE OF CONTENTS
Contents Page

1.0 - EXECUTIVE SUMMARY 1-1

1.1 - Introduction 1-1

1.2 – Purpose of Study 1-1

1.3 - Existing System Review 1-1

1.3. - Total ESMP Cost Estimate 1-2

2.0 - SYSTEM PLANNING CRITERIA 2-1

2.1 – Distribution System Planning Criteria 2-1

2.1.1 – Distribution System Design Criteria 2-1

2.2 – Substation Planning Criteria 2-2

2.3 – Basis of Cost Estimates 2-2

3.0 - LOAD FORECAST 3-1

4.0 - LAND USE PROJECTION 4-1

5.0 - 5-YEAR CAPITAL IMPROVEMENT PLAN (CIP) 5-1

5.1 - Executive Summary 5-5

5.1.1 - Introduction 5-5

5.1.2 - Purpose of Study 5-5

5.1.3 - General Conclusions and Recommendations 5-5

5.2 - Planning Criteria 5-7

5.2.1 - Distribution System 5-7

5.2.2 - Substation 5-8

5.2.3 - Basis of Cost Estimates 5-8

5.3 - System Forecast 5-11

5.4 - Overhead Maintenance Program 5-26

5.5 - Capital Maintenance Project 5-27

5.6 - Substation Capacity Analysis 5-46

5.7 - Distribution System Analysis 5-47

5.8 - Total 5-Year CIP Cost Estimate 5-75

6.0 - 15-Year ESMP 6-1

6.1 - Overhead Maintenance Program 6-1

6.2 - Capital Maintenance Projects 6-3

6.3 - Substation Capacity Analysis 6-4

6.4 - Distribution System Analysis 6-5

6.5 - Total 15-Year ESMP Cost Estimate 6-37

7.0 - Electric Service Master Plan (ESMP) Summary 7-1

7.1 - Total Overhead Maintenance Program 7-1

7.2 - Total Capital Maintenance Projects 7-1

7.3 - Total Distribution System Improvement Projects 7-1

7.4 - Total ESMP Cost Estimate 7-2
16218

TABLE OF CONTENTS
List of Table, Charts, and Images Page
Table 1.4-1 – Total ESMP Cost Estimate 1-2
Table 2.3-1 – Conductor Material Cost 2-2
Table 2.3-2 – Pole Material Cost 2-2
Table 2.3-3 – Transformer Material Cost 2-3
Table 2.3-4 – Framing Units Material Cost 2-3
Table 2.3-5 – Underground Material Cost 2-4
Table 2.3-6 – Overhead Construction Labor and Fleet Cost 2-4 Table 2.3-7 – Underground Construction Labor and Fleet Cost 2-4 Banning Electric Utility Demand Forecast Table 3-2
Banning Electric Utility Non-Coincident System Peak Forecast Chart 3-3 Banning Electric Utility Coincident System Forecast Chart 3-4 Conceptual Banning Electric Utility Coincident System Forecast Chart 3-5 Banning Electric Utility MWH Purchases Chart 3-9
San Gorgonio Total kW Demand Chart 3-10
Midway Total kW Demand Chart 3-11
22nd Street Total kW Demand Chart 3-12
Stagecoach Total kW Demand Chart 3-13
Ivy Total kW Demand Chart 3-14
Sunset Total kW Demand Chart 3-15
Table 4.0-1 – Current Developments 4-1
Table 4.0-2 – Future Developments 4-1
5-Year CIP Table of Contents 5-3
Table 5.2.3-1 – Conductor Material Cost 5-8
Table 5.2.3-2 Pole Material Cost 5-8
Table 5.2.3-3 Transformer Material Cost 5-9
Table 5.2.3-4 Framing Units Material Cost 5-9
Table 5.2.3-5 Underground Material Cost 5-10
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost 5-10 Table 5.2.3-7 Underground Construction Labor and Fleet Cost 5-10 Banning Electric Utility Demand Forecast Table 5-12
Banning Electric Utility Non-Coincident System Peak Forecast Chart 5-13 Banning Electric Utility Coincident System Forecast Chart 5-14 Conceptual Banning Electric Utility Coincident System Forecast Chart 5-15 Banning Electric Utility MWH Purchases Chart 5-19
San Gorgonio Total kW Demand Chart 5-20
Midway Total kW Demand Chart 5-21
22nd Street Total kW Demand Chart 5-22
Stagecoach Total kW Demand Chart 5-23
Ivy Total kW Demand Chart 5-24
Sunset Total kW Demand Chart 5-25
Table 5.4-1 – Overhead Maintenance Program Costs 5-26
Table 5.5-1 – Capital Maintenance Project Costs 5-27
Table 5.6-1 – Substation Capacity Analysis 5-46
16319

TABLE OF CONTENTS
Image 5.7-1 – CIP Project 1 5-48
Image 5.7-2 – CIP Project 2 5-49
Image 5.7-3 – CIP Project 3 5-50
Image 5.7-4 – CIP Project 4 5-51
Image 5.7-5 – CIP Project 5 5-52
Image 5.7-6 – CIP Project 6 5-53
Image 5.7-7 – CIP Project 7 5-54
Image 5.7-8 – CIP Project 8 5-55
Image 5.7-9 – CIP Project 9 5-56
Image 5.7-10 – CIP Project 10 5-57
Image 5.7-11 – CIP Project 11 5-58
Image 5.7-12 – CIP Project 12 5-59
Image 5.7-13 – CIP Project 13 5-60
Image 5.7-14 – CIP Project 14 5-61
Image 5.7-15 – CIP Project 15 5-62
Image 5.7-16 – CIP Project 16 5-63
Image 5.7-17 – CIP Project 17 5-64
Image 5.7-18 – CIP Project 18 5-65
Image 5.7-19 – CIP Project 19 5-66
Image 5.7-20 – CIP Project 20 5-67
Image 5.7-21 – CIP Project 21 5-68
Image 5.7-22 – CIP Project 22 5-69
Image 5.7-23 – CIP Project 23 5-70
Image 5.7-24 – CIP Project 24 5-71
Image 5.7-25 – CIP Project 25 5-72
Image 5.7-26 – CIP Project 26 5-73
Image 5.7-27 – CIP Project 27 5-74
Table 5.8-1 – Total 5-Year CIP Cost Estimate 5-75
Table 6.1-1 – Overhead Maintenance Program Costs 2031 thru 2035 6-1 Table 6.1-2 – Overhead Maintenance Program Costs 2036 thru 2040 6-2 Table 6.1-3 – Overhead Maintenance Program Costs 2041 thru 2045 6-2 Table 6.2-1 – Capital Maintenance Project Costs 6-3
Table 6.3-1 – Substation Capacity Analysis 6-4
Image 6.4-1 – ESMP Project 1 6-6
Image 6.4-2 – ESMP Project 2 6-7
Image 6.4-3 – ESMP Project 3 6-8
Image 6.4-4 – ESMP Project 4 6-9
Image 6.4-5 – ESMP Project 5 6-10
Image 6.4-6 – ESMP Project 6 6-11
Image 6.4-7 – ESMP Project 7 6-12
Image 6.4-8 – ESMP Project 8 6-13
Image 6.4-9 – ESMP Project 9 6-14
Image 6.4-10 – ESMP Project 10 6-15
Image 6.4-11 – ESMP Project 11 6-16
16420

TABLE OF CONTENTS
Image 6.4-12 – ESMP Project 12 6-17
Image 6.4-13 – ESMP Project 13 6-18
Image 6.4-14 – ESMP Project 14 6-19
Image 6.4-15 – ESMP Project 15 6-20
Image 6.4-16 – ESMP Project 16 6-21
Image 6.4-17 – ESMP Project 17 6-22
Image 6.4-18 – ESMP Project 18 6-23
Image 6.4-19 – ESMP Project 19 6-24
Image 6.4-20 – Feeder Plan for CKT’s 75, 76, and 78 6-25 Image 6.4-21 – ESMP Project 20 6-26
Image 6.4-22 – ESMP Project 21 6-27
Image 6.4-23 – ESMP Project 22 6-28
Image 6.4-24 – ESMP Project 23 6-29
Image 6.4-25 – ESMP Project 24 6-30
Image 6.4-26 – ESMP Project 25 6-31
Image 6.4-27 – ESMP Project 26 6-32
Image 6.4-28 – ESMP Project 27 6-33
Image 6.4-29 – ESMP Project 28 6-34
Image 6.4-30 – ESMP Project 29 6-35
Image 6.4-31 – ESMP Project 30 6-36
Image 6.1-32 – Smith Creek Feeder Plan 6-36
Table 6.5-1 – 15-Year ESMP Cost Estimate (2031-2035) 6-37 Table 6.5-1 – 15-Year ESMP Cost Estimate (2036-2040) 6-38 Table 6.5-1 – 15-Year ESMP Cost Estimate (2040-2045) 6-39 Table 7.4-1 – 2026-2045 ESMP Cost Estimate 7-2
16521

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

1.0 - EXECUTIVE SUMMARY

1.1 - Introduction
The City of Banning owns the utility that provides electric service to Banning, California and the electric utility is maintained by Banning Electric Utility (BEU). Originally established in 1913 as a private utility, the City of Banning purchased the electric utility in 1922 and has been providing electric service to its residents since that time. Banning’s energy resource base includes portions of nuclear, geothermal, solar, landfill gas-to-energy, and hydro generating plants, that provide the majority of electricity required to meet the system peak demand.

Through an agreement with Southern California Edison Company (SCE), the BEU system utilizes SCE’s transmission system in bringing power from the California Independent System Operator (“CAISO”) controlled high voltage transmission grid to the BEU distribution system at the Banning Substation.

The City of Banning supports clean-energy and is committed to additional renewable energy resources to its already diverse portfolio. BEU has met and/or exceeded the renewable energy requirements of Compliance Period #1, Compliance Period #2, and Compliance Period #3 of the State’s Renewable Portfolio Standard (RPS) program. The Utility was 81 percent renewable in 2022, already exceeding the current State mandate of 60 percent by 2030.

BEU is a member of the Southern California Public Power Authority (SCPPA) enjoying the benefits of joint action through cost effective planning, construction, management, and operations of electrical energy resources.

1.2 - Purpose of Study
This Electric Service Master Plan (ESMP) is a report prepared by Finley Engineering Company, Inc. (FEC) based on an analysis and review of the historical system growth and operation to determine projections of future growth, recommendations for capital improvements, and scheduled system maintenance that will insure the continued economical and reliable operation of the system over the ensuing 20-year period.

The analysis was completed in two parts. The first 5-year analysis was completed as the Capital Improvement Plan (CIP) and includes projects and recommendations determined from the analysis, Capital Improvements specified by BEU, and Capital Maintenance also specified by BEU. This CIP will be presented to the City Council as the actual construction plan for the next 5 years. The 15 year ESMP analysis was completed as a guideline for determining the future system performance and improving system capacity for expansion.

1.3 – Existing System Review
BEU maintains three, 34.5 kV sub-transmission circuits totaling approximately eighteen miles which feed six distribution substations.

These six distribution substations have approximately 27 circuits feeding 147 miles of overhead and underground distribution line with an operating voltage of 7.2/12.5 kV. An estimated 47% of the total distribution line is underground.
1-1
16622

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Along these distribution lines, BEU serves approximately 15,570 consumer meters. In 2024, the BEU system experienced a coincident summer peak demand of 55.1 MW and a winter peak demand of 22.3 MW. Historically, the BEU system is a summer peaking system with the summer peak more than double the winter peak. Also in 2024, BEU purchased approximately 157,000 MWH’s through its portfolio of long-term power purchase agreements as well as purchases from the CAISO wholesale markets, distributed among the membership of Residential, Small Commercial, Medium Commercial, Industrial, Security Lighting, Street Lighting, and Well Service customers.

1.4 – Total ESMP Cost Estimate
Table 1.4-1 – Total ESMP Cost Estimate
2026-2045 Electric Service Master Plan
5-year CIP 15-Year ESMP Totals
OH Maintenance Program
Total Cost $4,058,438 $23,968,742 $28,027,180
CIAC $0 $0 $0
BEU Funding Cost $4,058,438 $23,968,742 $28,027,180
Capital-Maintenance Projects
Total Cost $20,784,500 $8,350,000 $29,134,500
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $11,490,750 $5,350,000 $16,840,750
System Improvement Projects
Total Cost $2,805,700 $11,539,300 $14,345,000
CIAC $0 $0 $0
BEU Funding Cost $2,805,700 $11,539,300 $14,345,000
Total ESMP Cost
Total Cost $27,648,638 $43,858,042 $71,506,680
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $18,354,888 $40,858,042 $59,212,930
Of the total cost, 47% is for the OH Maintenance Program, 28% is for Capital Maintenance Projects, and 24% is for System Improvement Projects.
1-2
16723

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

2.0 – SYSTEM PLANNING CRITERIA

2.1 - Distribution System Planning Criteria
The distribution projects contained in this ESMP are recommended based upon the following planning criteria.
a. With an assumed delivered voltage of 125 volts (1.041 per unit on a 120 volt base) during peak load conditions, the design minimum allowable voltage at the primary terminals of any distribution transformer shall be 118 volts (0.98 per unit on a 120 volt base). b. Voltage regulators and step transformers will be upgraded when projected peak loads exceed 85% of the device’s rating.
c. Sectionalizing devices will be upgraded when projected peak loads exceed 70% of the device’s continuous current rating.
d. Primary conductors on the 7.2/12.5 kV and below distribution system will be upgraded when projected peak loads exceed 60% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 60% of the conductor’s thermal rating
e. Primary conductors on the 34.5 kV sub-transmission system will be upgraded when projected peak loads exceed 90% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 90% of the conductor’s thermal rating
f. Single-phase primary voltage lines will be limited to 35 amps maximum loading. g. The power factor at the delivery point under peak loading conditions is desired to be no less than 95%. The off-peak power factor should preferably be maintained between 95% lagging and 95% leading. This criterion is subject to the cost of the installation of capacitors, switches, and controls vs. the cost of kilowatt (kW) loss reduction.

2.1.1 - Distribution System Design Criteria
The following design criteria was considered when determining projects contained in this ESMP. a. Feeder current balance will be maintained at plus or minus 20% of the average per phase loading during peak conditions. This criterion may be relaxed in areas where it could impose unnecessary or premature costs.
b. Conductor sizes will be economically sized but may be modified to conform to BEU’s standard conductor sizes.
c. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any load voltage or high conductor loading. d. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any high single-phase loading. For areas where there is no backfeed or load switch solution, additional conductors will be added to allow for phase balancing. 2-1
16824

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
e. Relocation of existing line sections will be considered where inaccessibility impedes the maintenance of line sections or jeopardizes the service or reliability of line sections.

2.2 – Substation Planning Criteria
The substation projects contained in this ESMP are recommended based upon the following planning criteria.
a. Substation transformers will limited to 95% of the max kVA rating of the transformer. The following improvements will be considered in the event the load exceeds 95% of the max kVA rating:
a. Load switching to adjacent substations
b. Upgrade of existing transformer
c. Installation of an additional transformer in the existing substation d. Construction of a new substation

2.3 – Basis of Cost Estimates
The following tables for material and labor costs were used to determine system improvement project costs. The costs were taken from actual prices provided by BEU as well as prices received by FEC from other sources.

Table 2.3-1 Conductor Material Cost
Conductor (price per foot)
OH Conductor UG Conductor
#2 Copper $1.31 1/0 AL, 15 kV $2.03
#2 ACSR $0.26 1/0 CU, 15 kV $10.98
#4 ACSR $0.15 1/0 CU, 35 kV $8.47
1/0 ACSR $0.30 4/0 CU $6.95
4/0 Copper $3.11 4/0 AL $4.97
4/0 ACSR $0.80 350 CU $7.53
336 ACSR $1.62 750 AL $13.38
Table 2.3-2 Pole Material Cost
Pole Price per unit Pole Price per unit
35' Douglas Fir, H2 $1,269.30 35’ Wood, Class 2 $1,067.38 40’ Wood, Class 2 $766.35
45' Douglas Fir, H2 $1,771.08 45’ Wood, Class 2 $953.80 50’ Wood, Class 2 $1,135.73
55' Douglas Fir, H2 $2,889.48 55’ Wood, Class 2 $918.72 60' Douglas Fir, H2 $2,945.89 60’ Wood, Class 2 $1,362.29 2-2
16925

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 2.3-3 Transformer Material Cost
Transformer Price per unit
10 kVA O.H. Transformer S-Type 7,200 $500.00
15 kVA 7,200, 120/240 DV S-Type $645.42
25 kVA 7,200, 120/240 DV S-Type $919.16
37 kVA 7,200, 120/240 DV S-Type $1,496.65
50 kVA 7,200 120/240 $3,992.05
75 kVA 3Ø 12,470/7,200 120/208 $6,023.22
300 kVA DV $8,583.61
750 kVA 3Ø 12,470/7,200 $14,626.30
1,000 kVA 3Ø 12,470/7,200 DV $10,809.48
2,500 kVA 3Ø 12,470/7,200 277/480 $34,539.92
25 kVA 1Ø 12,470/7,200 120/240 Pdmnt $3,685.34

37.5 kVA 1Ø 12,400/7,200 DV Pdmnt $1,988.01
75 kVA 1Ø 12,470/7,200 120/240 Pdmnt $7,110.42
300 kVA 3Ø 12,470/4,160 DV Pdmnt 208/120 $13,547.15
500 kVA 3Ø Pdmnt $10,442.65
1,500 kVA DV 3Ø Pdmnt 277/480 $31,037.04
Table 2.3-4 Framing Units Material Cost
Framing Unit Price per unit
A1.3P $75.32
A1.11P $493.46
A5.2G $286.41
A3.1 $78.74
A6.21 $1,080.29
G1.2 $317.41
G1.2 $1,318.96
A5.1 $195.12
A5.21 $888.35
(A4.1) $255.90
G1.3 $433.79
G1.3 $1,127.02
C1.11 $628.33
C1.81G $1,592.53
C1.11,A5.21 $1,516.68
C5.82G $3,472.80
C3.1 $208.96
C3.1,A5.1 $404.08
C3.1,A5.21 $1,097.31
C3.1, C5.1 $376.78
C5.1 $167.82
C5.1,A5.1 $362.94
C5.1,A5.21 $1,056.17
2-3
17026

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 2.3-5 Underground Material Cost
Material Price per unit
Light Duty Secondary Box $78.42
Light Duty Secondary Lid $83.43
4" PVC SCH 40 (per foot) $1.69
1/0 AL U/G (per foot) $4.75
Service Entrance Sleeve $0.45
Deadend Shoe Small $8.58
Power Solve (Pulling Lube) $58.98
Table 2.3-6 Overhead Construction Labor and Fleet Cost
Units
(hr.)
Unit Cost
(per hr.)
Utility Bed P/U 1 ton (Foreman) (2 hrs. per connection) 4 $27.78 2 Person Lift (Bucket Truck) 55' (2 hrs. per connection) 2 $51.68 4 Person Crew 4 $466.73
3 Person Crew (2 hours per connection) 4 $352.02
2 Person Crew 2 $237.31
Electrical Engineering Supervisor (0.5 hrs. per connection) 1 $125.98 Electric Service Planning Supervisor (0.5 hrs. per connection) 1 $127.97 GIS Technician (1 hr. per connection) 2 $59.21
For overhead line, project cost estimates are based on an average of construction 1 mile of line per month with average span lengths at 150’.

Table 2.3-7 Underground Construction Labor and Fleet Cost Labor Price per hr.
4 Person Line Crew $466.73
Powerline Crew Superintendent $135.93
Fleet Price per hr.

Dump Truck $55.98
Utility Bed P/U 1 ton (Foreman) (3) $27.78
Digger Derrick $48.77
Wire Puller $24.98
Reel Trailer $24.98
Backhoe $23.95
For underground line, project estimates are based on an average construction of 1 month to trench, lay conduit, pull wire and terminate, and backfill 300’.

Engineering (10%) and contingency (5%) were also added for each cost estimate. 2-4
17127

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

3.0 LOAD FORECAST
The demand forecast was prepared to project the summer and winter kW demand per substation area as well as the total system demand for the City of Banning for the 2026-2045 ESMP period.

The historical non-coincident substation demands as well as the historical coincident system demands were provided by BEU and used as the basis for the forecast. BEU also provided insight into new load additions that are in some sort of application or planning process and were used in the conceptual forecast.

Additional factors that were considered when reviewing the historical peaks include temporary load switching between substations, construction of new substations with permanent load switching, and removal and/or replacement of existing substations.

Along with new load additions, considerations were also made for the addition of EV chargers at new subdivision locations.

This forecast was used to run voltage drop and load flow analysis to determine system improvements required to reliably serve the City of Banning’s existing consumers and allow for future consumer growth.

It is projected that the BEU system will reach a non-coincident peak of 110,556 kW in the summer of 2045 and 81,410 kW in the winter of 2045. It is also projected that the BEU system will reach a coincident peak of 90,738 kW in the summer of 2045 and 75,580 kW in the winter of 2045.

A separate conceptual forecast was created to include new load additions that are in some state of application or planning process. It is projected that the BEU system will reach a conceptual non-coincident peak of 176,165 kW in the summer of 2045 and 161,007 kW in the winter of 2045.

As part of the historical review, MWH purchases were also reviewed and a forecast was determined. It is projected that the BEU system will have an annual coincident purchase of 272,571 MWH’s by 2045.

A graphical representation of the individual substation demand forecast as well as the total system coincident demand, non-coincident demand, conceptual non-coincident demand and MWH purchases is included following this page.
3-1
17228

BANNING ELECTRIC UTILTIY
2026-2045 ESMP SYSTEM FORECAST
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 San Gorgonio Total
S 16,425 17,079 16,472 9,131 4,958 16,500 16,830 17,167 17,510 17,860 18,217 18,582 18,953 19,332 19,719 20,113 20,516 20,926 21,345 21,771 22,207 22,651 23,104 23,566 24,037 24,518 2.0% W 15,022 12,746 11,267 7,193 3,739 15,000 15,300 15,606 15,918 16,236 16,561 16,892 17,230 17,575 17,926 18,285 18,651 19,024 19,404 19,792 20,188 20,592 21,004 21,424 21,852 22,289 2.0% Cannabis Cultivation 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 Yoshinoya 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 S 16,425 17,079 16,472 9,131 4,958 19,748 20,078 20,415 20,758 21,108 21,465 21,830 22,201 22,580 22,967 23,361 23,764 24,174 24,593 25,019 25,455 25,899 26,352 26,814 27,285 27,766 1.7% W 15,022 12,746 11,267 7,193 3,739 18,248 18,548 18,854 19,166 19,484 19,809 20,140 20,478 20,823 21,174 21,533 21,899 22,272 22,652 23,040 23,436 23,840 24,252 24,672 25,100 25,537 1.7% Midway Total
S 13,541 13,649 14,272 17,082 15,786 15,052 15,458 15,876 16,304 16,745 17,197 17,661 18,138 18,628 19,131 19,647 20,178 20,722 21,282 21,856 22,447 23,053 23,675 24,314 24,971 25,645 2.7% W 10,384 9,247 7,788 6,868 10,715 9,663 9,924 10,192 10,467 10,750 11,040 11,338 11,644 11,958 12,281 12,613 12,953 13,303 13,662 14,031 14,410 14,799 15,199 15,609 16,031 16,463 2.7% Airport
S 365 370 360 32 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% W 389 389 280 23 22 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% 22nd Street
S 10,233 10,319 9,736 10,585 11,240 10,670 10,787 10,906 11,026 11,147 11,270 11,394 11,519 11,646 11,774 11,904 12,034 12,167 12,301 12,436 12,573 12,711 12,851 12,992 13,135 13,280 1.1% W 8,140 6,529 6,105 6,567 8,018 8,210 8,300 8,392 8,484 8,577 8,672 8,767 8,863 8,961 9,059 9,159 9,260 9,362 9,465 9,569 9,674 9,781 9,888 9,997 10,107 10,218 1.1% Stagecoach
S 0 0 0 6,634 8,040 6,700 6,834 6,971 7,110 7,252 7,397 7,545 7,696 7,850 8,007 8,167 8,331 8,497 8,667 8,841 9,017 9,198 9,382 9,569 9,761 9,956 2.0% W 0 0 0 3,616 7,955 3,800 3,876 3,954 4,033 4,113 4,196 4,279 4,365 4,452 4,541 4,632 4,725 4,819 4,916 5,014 5,114 5,217 5,321 5,427 5,536 5,647 2.0% Ivy
S 0 0 5,308 7,206 8,333 5,400 5,508 5,618 5,731 5,845 5,962 6,081 6,203 6,327 6,453 6,583 6,714 6,849 6,985 7,125 7,268 7,413 7,561 7,713 7,867 8,024 2.0% W 0 0 4,493 4,890 6,235 4,500 4,590 4,682 4,775 4,871 4,968 5,068 5,169 5,272 5,378 5,485 5,595 5,707 5,821 5,938 6,056 6,178 6,301 6,427 6,556 6,687 2.0% Morongo Health Clinic 0 0 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 S 0 0 5,308 7,206 8,333 5,400 5,508 6,254 6,367 6,481 6,598 6,717 6,839 6,963 7,089 7,219 7,350 7,485 7,621 7,761 7,904 8,049 8,197 8,349 8,503 8,660 2.4% W 0 0 4,493 4,890 6,235 4,500 4,590 5,318 5,411 5,507 5,604 5,704 5,805 5,908 6,014 6,121 6,231 6,343 6,457 6,574 6,692 6,814 6,937 7,063 7,192 7,323 2.5% Sunset
S 8,140 8,099 9,586 11,441 14,821 10,439 10,857 11,291 11,742 12,212 12,701 13,209 13,737 14,286 14,858 15,452 16,070 16,713 17,382 18,077 18,800 19,552 20,334 21,147 21,993 22,873 4.0% W 6,716 5,803 5,037 8,299 11,443 6,319 6,572 6,835 7,108 7,392 7,688 7,996 8,315 8,648 8,994 9,354 9,728 10,117 10,522 10,942 11,380 11,835 12,309 12,801 13,313 13,846 4.0% Crestwood Communities 432 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 Vista Robles KB homes 0 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 S 8,140 8,099 9,586 11,441 14,821 10,871 13,233 13,667 14,118 14,588 15,077 15,585 16,113 16,662 17,234 17,828 18,446 19,089 19,758 20,453 21,176 21,928 22,710 23,523 24,369 25,249 4.3% W 6,716 5,803 5,037 8,299 11,443 6,751 8,948 9,211 9,484 9,768 10,064 10,372 10,691 11,024 11,370 11,730 12,104 12,493 12,898 13,318 13,756 14,211 14,685 15,177 15,689 16,222 4.5% Alola
S 2,929 2,370 1,646 372 0000000000000000000000 0.0%
W 2,377 708 782 336 0000000000000000000000 0.0%
Banning Electric Utility Non-Coincident System Peak Forecast S 51,632 51,885 57,380 62,482 63,207 68,441 71,898 74,088 75,683 77,322 79,004 80,732 82,507 84,330 86,202 88,126 90,103 92,134 94,221 96,367 98,571 100,837 103,167 105,562 108,024 110,556 2.4% W 43,029 35,422 35,752 37,792 48,126 51,172 54,186 55,919 57,045 58,200 59,385 60,600 61,847 63,127 64,440 65,788 67,172 68,592 70,050 71,546 73,083 74,661 76,281 77,945 79,654 81,410 2.3% Banning Electric Utility System Coincident Forecast
S 51,197 49,751 52,667 51,096 55,143 56,467 57,822 59,210 60,631 62,086 63,576 65,102 66,664 68,264 69,902 71,580 73,298 75,057 76,858 78,703 80,592 82,526 84,507 86,535 88,612 90,738 2.4% W 40,752 25,776 34,719 32,262 46,883 47,962 49,065 50,193 51,348 52,529 53,737 54,973 56,237 57,530 58,854 60,207 61,592 63,009 64,458 65,940 67,457 69,009 70,596 72,219 73,881 75,580 2.3% Conceptual Banning Electric Utility System Coincident Forecast S 51,197 49,751 52,667 51,096 55,143 56,467 58,962 61,201 69,810 76,184 86,777 100,472 109,135 120,377 129,082 137,336 145,321 153,347 157,527 161,751 166,019 167,953 169,934 171,962 174,039 176,165 5.9% W 40,752 25,776 34,719 32,262 46,883 47,962 50,205 52,185 60,527 66,627 76,938 90,343 98,708 109,643 118,034 125,963 133,615 141,299 145,127 148,988 152,884 154,436 156,023 157,646 159,308 161,007 6.2% Bridge-Morongo Logistics 0000 1,031 1,991 2,858 3,344 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 Sunset Crossroads 0 0 0 2,712 2,712 6,967 10,213 10,561 13,639 14,439 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 Rancho San Gorgonio 0 0 0 3,888 7,776 11,664 15,552 19,440 23,328 27,216 31,104 34,992 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 Mission Heights 000000 2,379 4,758 7,137 9,516 11,895 14,274 16,653 19,032 21,411 23,790 23,790 23,790 23,790 23,790 23,790 First Hathaway Logistics 0 0 0 0 0 0 471 471 471 471 471 471 471 471 471 471 471 471 471 471 471 Banning Commerce Center 0 0 0 0 0 0 438 438 438 438 438 438 438 438 438 438 438 438 438 438 438 WEKA 007777777777777777777
Charles St. CDRE 0 0 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 KCB Towers 0 0 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 Pallet Yard 007777777777777777777
First Lincoln Logistics 0 0 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 Brown Strauss 0 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 Wyndam Micro Hotel 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 DR Horton 0 0 588 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 Atwell Large Retail 0 0 0 0 0 0 880 880 880 880 880 880 880 880 880 880 880 880 880 880 880 2025-2045
Annual
Growth Rate
Historical Forecast
Peak kW Demand
3-2
17329
.00

80.0060.0040.0020.00
120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY NON-COINCIDENT SYSTEM PEAK FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
3-3
17430
.00

90.0080.0070.0060.0050.0040.0030.0020.0010.00
100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
3-4
17531
.00

80.0060.0040.0020.00
200.00180.00160.00140.00120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

CONCEPTUAL BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

6.2% ANNUAL GROWTH
RATE

SUMMER-FORECAST

5.9% ANNUAL GROWTH
RATE
3-5
17632

BANNING ELECTRIC UTILITY
2026-2045 ESMP NON-COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 11,577 21.27 12,259 22.52 12,651 23.24 12,906 23.71 13,167 24.19 13,435 24.68 13,710 25.19 Feb 10,470 21.33 11,086 22.58 11,441 23.31 11,671 23.78 11,907 24.26 12,150 24.75 12,399 25.26 Mar 10,870 20.69 11,511 21.91 11,879 22.61 12,118 23.07 12,363 23.54 12,615 24.01 12,873 24.51 Apr 13,733 32.53 14,427 34.18 14,867 35.22 15,187 35.98 15,515 36.76 15,853 37.56 16,200 38.38 May 15,631 37.92 16,420 39.84 16,920 41.05 17,285 41.94 17,659 42.85 18,043 43.78 18,438 44.74 Jun 18,497 56.73 19,432 59.59 20,023 61.41 20,455 62.73 20,897 64.09 21,352 65.48 21,819 66.92 Jul 25,788 65.86 27,090 69.19 27,915 71.29 28,517 72.83 29,134 74.40 29,768 76.02 30,419 77.69 Aug 26,719 68.44 28,069 71.90 28,923 74.09 29,546 75.68 30,186 77.32 30,843 79.00 31,517 80.73 Sep 21,335 64.10 22,413 67.34 23,096 69.39 23,593 70.88 24,104 72.42 24,628 73.99 25,167 75.61 Oct 19,525 51.17 20,675 54.19 21,336 55.92 21,766 57.05 22,206 58.20 22,658 59.38 23,122 60.60 Nov 10,787 21.08 11,423 22.32 11,788 23.04 12,025 23.50 12,269 23.98 12,518 24.46 12,775 24.97 Dec 12,073 22.02 12,784 23.31 13,193 24.06 13,458 24.54 13,731 25.04 14,010 25.55 14,297 26.07 TOTAL: 197,005 207,588 214,032 218,526 223,138 227,873 232,734 Summer Peak (MW) 68.44 71.90 74.09 75.68 77.32 79.00 80.73 Winter Peak (MW) 51.17 54.19 55.92 57.05 58.20 59.38 60.60 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 13,992 25.71 14,282 26.24 14,579 26.79 14,884 27.35 15,197 27.92 15,518 28.51 15,848 29.12 Feb 12,654 25.78 12,916 26.31 13,184 26.86 13,460 27.42 13,743 28.00 14,034 28.59 14,332 29.20 Mar 13,138 25.01 13,410 25.53 13,689 26.06 13,975 26.60 14,269 27.16 14,571 27.74 14,880 28.33 Apr 16,556 39.22 16,922 40.09 17,297 40.98 17,683 41.89 18,080 42.83 18,488 43.80 18,907 44.79 May 18,843 45.72 19,259 46.73 19,687 47.77 20,126 48.83 20,578 49.93 21,042 51.05 21,518 52.21 Jun 22,299 68.39 22,791 69.90 23,297 71.45 23,817 73.04 24,352 74.68 24,901 76.37 25,465 78.10 Jul 31,087 79.39 31,774 81.15 32,480 82.95 33,205 84.80 33,950 86.70 34,715 88.66 35,501 90.67 Aug 32,210 82.51 32,922 84.33 33,653 86.20 34,404 88.13 35,176 90.10 35,969 92.13 36,783 94.22 Sep 25,720 77.27 26,288 78.98 26,872 80.74 27,472 82.54 28,088 84.39 28,721 86.29 29,372 88.25 Oct 23,598 61.85 24,086 63.13 24,587 64.44 25,102 65.79 25,630 67.17 26,171 68.59 26,728 70.05 Nov 13,038 25.48 13,307 26.01 13,584 26.55 13,868 27.10 14,160 27.67 14,459 28.26 14,767 28.86 Dec 14,591 26.61 14,893 27.16 15,203 27.73 15,521 28.31 15,847 28.90 16,182 29.51 16,526 30.14 TOTAL: 237,725 242,850 248,113 253,518 259,069 264,770 270,627 Summer Peak (MW) 82.51 84.33 86.20 88.13 90.10 92.13 94.22 Winter Peak (MW) 61.85 63.13 64.44 65.79 67.17 68.59 70.05 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 16,187 29.74 16,534 30.38 16,891 31.03 17,258 31.71 17,634 32.40 18,021 33.11 18,418 33.84 Feb 14,638 29.82 14,953 30.46 15,275 31.12 15,607 31.79 15,947 32.49 16,297 33.20 16,656 33.93 Mar 15,198 28.93 15,525 29.55 15,860 30.19 16,204 30.85 16,558 31.52 16,921 32.21 17,294 32.92 Apr 19,337 45.81 19,779 46.86 20,234 47.93 20,702 49.04 21,182 50.18 21,676 51.35 22,184 52.55 May 22,008 53.40 22,512 54.62 23,029 55.88 23,561 57.17 24,108 58.49 24,671 59.86 25,249 61.26 Jun 26,044 79.88 26,640 81.70 27,253 83.58 27,882 85.51 28,530 87.50 29,195 89.54 29,879 91.64 Jul 36,310 92.73 37,140 94.85 37,994 97.03 38,872 99.27 39,774 101.58 40,702 103.95 41,656 106.38 Aug 37,621 96.37 38,482 98.57 39,366 100.84 40,276 103.17 41,211 105.56 42,172 108.02 43,160 110.56 Sep 30,041 90.26 30,728 92.32 31,434 94.44 32,161 96.63 32,907 98.87 33,675 101.17 34,464 103.55 Oct 27,299 71.55 27,885 73.08 28,487 74.66 29,105 76.28 29,740 77.95 30,392 79.65 31,062 81.41 Nov 15,082 29.47 15,406 30.11 15,739 30.76 16,080 31.43 16,431 32.11 16,791 32.82 17,161 33.54 Dec 16,879 30.78 17,242 31.44 17,614 32.12 17,996 32.82 18,389 33.54 18,792 34.27 19,206 35.03 TOTAL: 276,644 282,826 289,178 295,705 302,412 309,305 316,390 Summer Peak (MW) 96.37 98.57 100.84 103.17 105.56 108.02 110.56 Winter Peak (MW) 71.55 73.08 74.66 76.28 77.95 79.65 81.41 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
3-6
17733

BANNING ELECTRIC UTILITY
2026-2045 ESMP COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,100 20.39 11,356 20.86 11,617 21.34 11,884 21.83 12,157 22.34 12,437 22.85 Feb 9,813 19.99 10,038 20.45 10,269 20.92 10,506 21.40 10,747 21.89 10,994 22.40 11,247 22.91 Mar 10,188 19.40 10,423 19.84 10,662 20.30 10,908 20.76 11,158 21.24 11,415 21.73 11,678 22.23 Apr 11,331 26.84 11,603 27.49 11,881 28.15 12,166 28.82 12,458 29.51 12,757 30.22 13,063 30.95 May 12,896 31.29 13,205 32.04 13,522 32.81 13,847 33.60 14,179 34.40 14,519 35.23 14,868 36.07 Jun 15,261 46.80 15,627 47.93 16,002 49.08 16,386 50.25 16,780 51.46 17,182 52.70 17,595 53.96 Jul 21,276 54.34 21,787 55.64 22,309 56.98 22,845 58.34 23,393 59.74 23,955 61.18 24,529 62.65 Aug 22,044 56.47 22,573 57.82 23,115 59.21 23,670 60.63 24,238 62.09 24,820 63.58 25,415 65.10 Sep 17,603 52.89 18,025 54.16 18,458 55.45 18,901 56.79 19,354 58.15 19,819 59.54 20,294 60.97 Oct 18,300 47.96 18,721 49.06 19,151 50.19 19,592 51.35 20,042 52.53 20,503 53.74 20,975 54.97 Nov 10,110 19.76 10,343 20.21 10,581 20.68 10,824 21.15 11,073 21.64 11,328 22.14 11,588 22.65 Dec 11,315 20.64 11,575 21.11 11,842 21.60 12,114 22.09 12,393 22.60 12,678 23.12 12,969 23.65 TOTAL: 170,987 175,020 179,149 183,374 187,700 192,127 196,659 Summer Peak (MW) 56.47 57.82 59.21 60.63 62.09 63.58 65.10 Winter Peak (MW) 47.96 49.06 50.19 51.35 52.53 53.74 54.97 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 12,723 23.38 13,016 23.91 13,315 24.46 13,621 25.03 13,935 25.60 14,255 26.19 14,583 26.79 Feb 11,506 23.44 11,771 23.98 12,041 24.53 12,318 25.09 12,602 25.67 12,891 26.26 13,188 26.86 Mar 11,946 22.74 12,221 23.26 12,502 23.80 12,790 24.35 13,084 24.91 13,385 25.48 13,693 26.07 Apr 13,377 31.69 13,698 32.45 14,027 33.23 14,363 34.03 14,708 34.84 15,061 35.68 15,422 36.54 May 15,225 36.94 15,590 37.83 15,964 38.73 16,347 39.66 16,740 40.62 17,142 41.59 17,553 42.59 Jun 18,017 55.26 18,449 56.58 18,892 57.94 19,346 59.33 19,810 60.75 20,285 62.21 20,772 63.71 Jul 25,118 64.15 25,721 65.69 26,338 67.27 26,970 68.88 27,618 70.53 28,281 72.23 28,959 73.96 Aug 26,025 66.66 26,650 68.26 27,289 69.90 27,944 71.58 28,615 73.30 29,302 75.06 30,005 76.86 Sep 20,781 62.44 21,280 63.94 21,791 65.47 22,314 67.04 22,849 68.65 23,398 70.30 23,959 71.98 Oct 21,457 56.24 21,951 57.53 22,456 58.85 22,972 60.21 23,501 61.59 24,041 63.01 24,594 64.46 Nov 11,855 23.17 12,128 23.70 12,406 24.25 12,692 24.80 12,984 25.37 13,282 25.96 13,588 26.55 Dec 13,268 24.20 13,573 24.75 13,885 25.32 14,204 25.90 14,531 26.50 14,865 27.11 15,207 27.73 TOTAL: 201,298 206,047 210,907 215,882 220,975 226,188 231,523 Summer Peak (MW) 66.66 68.26 69.90 71.58 73.30 75.06 76.86 Winter Peak (MW) 56.24 57.53 58.85 60.21 61.59 63.01 64.46 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 14,918 27.41 15,261 28.04 15,612 28.68 15,971 29.34 16,339 30.02 16,715 30.71 17,099 31.42 Feb 13,491 27.48 13,801 28.11 14,119 28.76 14,444 29.42 14,776 30.10 15,116 30.79 15,463 31.50 Mar 14,007 26.67 14,330 27.28 14,659 27.91 14,996 28.55 15,341 29.20 15,694 29.88 16,055 30.56 Apr 15,793 37.41 16,172 38.31 16,560 39.23 16,957 40.17 17,364 41.14 17,781 42.12 18,208 43.13 May 17,974 43.61 18,406 44.66 18,847 45.73 19,300 46.83 19,763 47.95 20,237 49.10 20,723 50.28 Jun 21,271 65.23 21,781 66.80 22,304 68.40 22,839 70.04 23,387 71.73 23,949 73.45 24,523 75.21 Jul 29,654 75.73 30,366 77.55 31,095 79.41 31,841 81.32 32,605 83.27 33,388 85.27 34,189 87.32 Aug 30,725 78.70 31,462 80.59 32,218 82.53 32,991 84.51 33,783 86.53 34,593 88.61 35,424 90.74 Sep 24,534 73.71 25,123 75.48 25,726 77.29 26,344 79.15 26,976 81.05 27,623 82.99 28,286 84.98 Oct 25,160 65.94 25,738 67.46 26,330 69.01 26,936 70.60 27,555 72.22 28,189 73.88 28,838 75.58 Nov 13,900 27.17 14,220 27.79 14,547 28.43 14,882 29.08 15,224 29.75 15,574 30.44 15,932 31.14 Dec 15,557 28.37 15,915 29.02 16,281 29.69 16,655 30.37 17,038 31.07 17,430 31.79 17,831 32.52 TOTAL: 236,985 242,576 248,298 254,156 260,152 266,289 272,571 Summer Peak (MW) 78.70 80.59 82.53 84.51 86.53 88.61 90.74 Winter Peak (MW) 65.94 67.46 69.01 70.60 72.22 73.88 75.58 Projected Load Data 2039-2045
Projected Load Data 2032-2038
2039 2040 2041 2042 2043 2044 2045
Projected Load Data 2025 - 2031
2032 2033 2034 2035 2036 2037 2038
2025 2026 2027 2028 2029 2030 2031
3-7
17834

BANNING ELECTRIC UTILITY
2026-2045 ESMP CONCEPTUAL COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,358 20.87 11,806 21.69 13,693 25.16 15,074 27.69 17,406 31.98 20,439 37.55 Feb 9,813 19.99 10,272 20.92 10,677 21.75 12,384 25.23 13,632 27.77 15,741 32.07 18,484 37.65 Mar 10,188 19.40 10,665 20.30 11,085 21.10 12,857 24.48 14,153 26.94 16,344 31.11 19,191 36.53 Apr 11,331 26.84 11,831 28.03 12,281 29.09 14,008 33.19 15,287 36.22 17,413 41.25 20,161 47.76 May 12,896 31.29 13,466 32.67 13,977 33.91 15,943 38.68 17,399 42.22 19,818 48.08 22,946 55.67 Jun 15,261 46.80 15,935 48.87 16,540 50.73 18,867 57.86 20,590 63.15 23,453 71.93 27,154 83.28 Jul 21,276 54.34 22,216 56.74 23,060 58.89 26,303 67.18 28,705 73.31 32,696 83.50 37,856 96.68 Aug 22,044 56.47 23,018 58.96 23,892 61.20 27,253 69.81 29,742 76.18 33,877 86.78 39,223 100.47 Sep 17,603 52.89 18,380 55.22 19,078 57.32 21,762 65.38 23,749 71.35 27,051 81.27 31,320 94.10 Oct 18,300 47.96 19,156 50.20 19,911 52.18 23,094 60.53 25,421 66.63 29,356 76.94 34,470 90.34 Nov 10,110 19.76 10,583 20.68 11,001 21.50 12,759 24.94 14,045 27.45 16,219 31.70 19,044 37.22 Dec 11,315 20.64 11,844 21.60 12,312 22.45 14,280 26.04 15,719 28.67 18,151 33.10 21,314 38.87 TOTAL: 170,987 178,725 185,621 213,204 233,515 267,525 311,603 Summer Peak (MW) 56.47 58.96 61.20 69.81 76.18 86.78 100.47 Winter Peak (MW) 47.96 50.20 52.18 60.53 66.63 76.94 90.34 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 22,332 41.03 24,806 45.58 26,704 49.06 28,498 52.36 30,229 55.54 31,967 58.73 32,833 60.32 Feb 20,195 41.14 22,433 45.70 24,149 49.19 25,772 52.50 27,337 55.69 28,909 58.89 29,692 60.49 Mar 20,968 39.92 23,291 44.34 25,073 47.73 26,758 50.94 28,383 54.03 30,016 57.14 30,829 58.69 Apr 21,899 51.88 24,155 57.22 25,902 61.36 27,558 65.29 29,160 69.08 30,771 72.90 31,610 74.88 May 24,924 60.47 27,492 66.70 29,480 71.53 31,365 76.10 33,188 80.53 35,021 84.97 35,976 87.29 Jun 29,495 90.46 32,534 99.78 34,886 106.99 37,117 113.83 39,275 120.45 41,444 127.10 42,574 130.57 Jul 41,121 105.02 45,356 115.84 48,637 124.21 51,746 132.15 54,755 139.84 57,779 147.56 59,354 151.58 Aug 42,606 109.14 46,994 120.38 50,393 129.08 53,615 137.34 56,732 145.32 59,866 153.35 61,498 157.53 Sep 34,021 102.21 37,526 112.74 40,239 120.90 42,812 128.63 45,301 136.11 47,803 143.62 49,107 147.54 Oct 37,662 98.71 41,835 109.64 45,036 118.03 48,061 125.96 50,981 133.62 53,913 141.30 55,373 145.13 Nov 20,808 40.66 23,113 45.17 24,882 48.63 26,553 51.89 28,166 55.05 29,786 58.21 30,593 59.79 Dec 23,287 42.47 25,867 47.17 27,847 50.78 29,718 54.20 31,523 57.49 33,336 60.79 34,239 62.44 TOTAL: 339,319 375,401 403,228 429,573 455,032 480,611 493,678 Summer Peak (MW) 109.14 120.38 129.08 137.34 145.32 153.35 157.53 Winter Peak (MW) 98.71 109.64 118.03 125.96 133.62 141.30 145.13 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 33,707 61.93 34,588 63.55 34,939 64.19 35,298 64.85 35,666 65.53 36,042 66.22 36,426 66.93 Feb 30,483 62.10 31,280 63.72 31,597 64.37 31,922 65.03 32,254 65.70 32,594 66.40 32,941 67.10 Mar 31,649 60.25 32,477 61.82 32,806 62.45 33,143 63.09 33,488 63.75 33,841 64.42 34,202 65.11 Apr 32,457 76.89 33,314 78.92 33,702 79.84 34,099 80.78 34,506 81.75 34,923 82.73 35,350 83.74 May 36,941 89.63 37,915 91.99 38,357 93.07 38,810 94.16 39,273 95.29 39,747 96.44 40,233 97.62 Jun 43,716 134.07 44,869 137.61 45,392 139.21 45,927 140.85 46,475 142.53 47,037 144.25 47,611 146.02 Jul 60,946 155.65 62,554 159.76 63,283 161.62 64,029 163.52 64,793 165.47 65,575 167.47 66,377 169.52 Aug 63,146 161.75 64,813 166.02 65,568 167.95 66,341 169.93 67,133 171.96 67,943 174.04 68,774 176.17 Sep 50,423 151.49 51,754 155.49 52,357 157.30 52,974 159.16 53,606 161.06 54,254 163.00 54,917 164.99 Oct 56,847 148.99 58,333 152.88 58,925 154.44 59,531 156.02 60,150 157.65 60,784 159.31 61,432 161.01 Nov 31,407 61.38 32,228 62.98 32,555 63.62 32,890 64.28 33,232 64.95 33,582 65.63 33,941 66.33 Dec 35,150 64.10 36,069 65.78 36,435 66.45 36,809 67.13 37,192 67.83 37,584 68.54 37,985 69.27 TOTAL: 506,871 520,193 525,915 531,773 537,769 543,906 550,188 Summer Peak (MW) 161.75 166.02 167.95 169.93 171.96 174.04 176.17 Winter Peak (MW) 148.99 152.88 154.44 156.02 157.65 159.31 161.01 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
3-8
17935
0 50
300250200150100
'19 '20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MWH (x1,000)
YEAR

BANNING ELECTRIC UTILTIY MWH PURCHASES

HISTORICAL

FORECAST

2.4% ANNUAL GROWTH
RATE
3-9
18036
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SAN GORGONIO TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.7% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.7% ANNUAL GROWTH
RATE
3-10
18137
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
MIDWAY TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

SUMMER-FORECAST

2.7% ANNUAL GROWTH
RATE

WINTER-FORECAST

2.7% ANNUAL GROWTH
RATE
3-11
18238
0 8,0006,0004,0002,000
14,00012,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
22ND STREET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.1% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.1% ANNUAL GROWTH
RATE
3-12
18339
0 8,0006,0004,0002,000
12,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
STAGECOACH kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
3-13
18440
0 9,0008,0007,0006,0005,0004,0003,0002,0001,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
IVY kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
3-14
18541
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SUNSET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

4.5% ANNUAL GROWTH
RATE

SUMMER-FORECAST

4.3% ANNUAL GROWTH
RATE
3-15
18642

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

4.0 – LAND USE AND POPULATION
The City of Banning is located in Riverside County and has a reported 2026 population of approximately 33,000 people which has increased by an estimated 10% since the most recent census in 2020. The annual growth rate is projected at 1.6% The BEU service area for the most part is the same as the Banning City Boundary which covers approximately 23 square miles.

The following table shows current development whose load was included in the ESMP analysis.

Table 4.0-1 – Current Developments
Development Classification Land Area (acres) Size
Atwell Subdivision Residential 1,457 14,000 + lots
Cannabis Cultivation Industrial 0.5 -
Yoshinoya Commercial - -
Morongo Health Clinic Commercial - -
Crestwood Communities Residential 5.9 19 lots
Vista Robles Homes Residential 72 140 lots
The following table shows future developments whose load was included in the ESMP analysis.

Table 4.0-2 – Future Developments
Development Classification Land Area (acres) Size
Bridge-Morongo Logistics Commercial/Industrial 509 5 buildings Sunset Crossroads Commercial/Industrial 559 6 buildings Rancho San Gorgonio Residential 710 3,600 lots
Mission Heights Residential - 2,200 lots
First Hathaway Logistics Commercial/Industrial 88 -
Banning Commerce Center Industrial 124 -
WEKA Industrial 3.4 -
Charlles St. CDRE Industrial 4.6 -
KCB Towers Industrial 4.5 -
Pallet Yard Industrial 0.3 -
First Lincoln Logistics Commercial 6.2 -
Brown Strauss Commercial 15.8 -
Wyndam Micro Hotel Residential/Commercial 1.3 -
DR Horton Residential - 98 lots
Atwell Large Retail Commercial - -
4-1
18743

CITY OF BANNING, CALIFORNIA
2026-2030 5-YEAR CAPITAL IMPROVEMENT PLAN
April 2026
Prepared by:

Finley Engineering Company, Inc.

On behalf of:

Banning Electric Utility
Contact Information:

Finley Engineering Company, Inc.

PO Box 148, 104 E. 11th Street
Lamar, MO 64795
417.682.5531
www.finleyusa.com
City of Banning
99 E. Ramsey Street
Banning, CA 92220
951.922.3100
www.banningca.gov
5-1
18844

ENGINEERS CERTIFICATION
I, Christopher Adam Smart, P.E., herby certify that this 2026-2030 5-Year Capital Improvement Plan was prepared by me or under my direct Supervision and that I am a duly Licensed Professional Engineer under the laws of the state of California, license number E 25395.

X
5-2
18945

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

TABLE OF CONTENTS
Section Page

5.0 - 5-Year Construction Improvement Plan (CIP) 5-1

5.1 - Executive Summary 5-5

5.1.1 - Introduction 5-5

5.1.2 - Purpose of Study 5-5

5.1.3 - General Conclusions and Recommendations 5-5

5.2 - Planning Criteria 5-7

5.2.1 - Distribution System 5-7

5.2.2 - Substation 5-8

5.2.3 - Basis of Cost Estimates 5-8

5.3 - System Forecast 5-11

5.4 - Overhead Maintenance Program 5-26

5.5 - Capital Maintenance Project 5-27

5.6 - Substation Capacity Analysis 5-46

5.7 - Distribution System Analysis 5-47

5.8 - Total Cost Estimate 5-75
List of Table, Charts, and Images Page
Table 5.2.3-1 – Conductor Material Cost 5-8
Table 5.2.3-2 Pole Material Cost 5-8
Table 5.2.3-3 Transformer Material Cost 5-9
Table 5.2.3-4 Framing Units Material Cost 5-9
Table 5.2.3-5 Underground Material Cost 5-10
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost 5-10 Table 5.2.3-7 Underground Construction Labor and Fleet Cost 5-10 Banning Electric Utility Demand Forecast Table 5-12
Banning Electric Utility Non-Coincident System Peak Forecast Chart 5-13 Banning Electric Utility Coincident System Forecast Chart 5-14 Conceptual Banning Electric Utility Coincident System Forecast Chart 5-15 Banning Electric Utility MWH Purchases Chart 5-19
San Gorgonio Total kW Demand Chart 5-20
Midway Total kW Demand Chart 5-21
22nd Street Total kW Demand Chart 5-22
Stagecoach Total kW Demand Chart 5-23
Ivy Total kW Demand Chart 5-24
Sunset Total kW Demand Chart 5-25
Table 5.4-1 – Overhead Maintenance Program Costs 5-26
Table 5.5-1 – Capital Maintenance Project Costs 5-27
Table 5.6-1 – Substation Capacity Analysis 5-46
5-3
19046

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Image 5.7-1 – CIP Project 1 5-48
Image 5.7-2 – CIP Project 2 5-49
Image 5.7-3 – CIP Project 3 5-50
Image 5.7-4 – CIP Project 4 5-51
Image 5.7-5 – CIP Project 5 5-52
Image 5.7-6 – CIP Project 6 5-53
Image 5.7-7 – CIP Project 7 5-54
Image 5.7-8 – CIP Project 8 5-55
Image 5.7-9 – CIP Project 9 5-56
Image 5.7-10 – CIP Project 10 5-57
Image 5.7-11 – CIP Project 11 5-58
Image 5.7-12 – CIP Project 12 5-59
Image 5.7-13 – CIP Project 13 5-60
Image 5.7-14 – CIP Project 14 5-61
Image 5.7-15 – CIP Project 15 5-62
Image 5.7-16 – CIP Project 16 5-63
Image 5.7-17 – CIP Project 17 5-64
Image 5.7-18 – CIP Project 18 5-65
Image 5.7-19 – CIP Project 19 5-66
Image 5.7-20 – CIP Project 20 5-67
Image 5.7-21 – CIP Project 21 5-68
Image 5.7-22 – CIP Project 22 5-69
Image 5.7-23 – CIP Project 23 5-70
Image 5.7-24 – CIP Project 24 5-71
Image 5.7-25 – CIP Project 25 5-72
Image 5.7-26 – CIP Project 26 5-73
Image 5.7-27 – CIP Project 27 5-74
Table 5.8-1 – Total 5-Year CIP Cost Estimate 5-75
5-4
19147

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.1 - EXECUTIVE SUMMARY

5.1.1 - Introduction
The City of Banning owns the utility that provides electric service to Banning, California and the electric utility is maintained by Banning Electric Utility (BEU). Originally established in 1913 as a private utility, the City of Banning purchased the electric utility in 1922 and has been providing electric service to its residents since that time. Banning’s energy resource base includes portions of nuclear, geothermal, solar, landfill gas-to-energy, and hydro generating plants, that provide the majority of electricity required to meet the system peak demand.

Through an agreement with Southern California Edison Company (SCE), the BEU system utilizes SEC’s transmission system in bringing power from the California Independent System Operator (“CAISO”) controlled high voltage transmission grid to the BEU distribution system at the Banning Substation. BEU maintains three, 34.5kV sub-transmission circuits totaling approximately eighteen miles which feed six distribution substations.

These six distribution substations have approximately 27 circuits feeding 147 miles of overhead and underground distribution line with an operating voltage of 7.2/12.5 kV. An estimated 47% of the total distribution line is underground.

The City of Banning supports clean-energy and is committed to additional renewable energy resources to its already diverse portfolio. BEU has met and/or exceeded the renewable energy requirements of Compliance Period #1, Compliance Period #2, and Compliance Period #3 of the State’s Renewables Portfolio Standard (RPS) program. The Utility was 81 percent renewable in 2022, already exceeding the current State mandate of 60 percent by 2030.

BEU is a member of the Southern California Public Power Authority (SCPPA) enjoying the benefits of joint action through cost effective planning, construction, management, and operations of electrical energy resources.

5.1.2 - Purpose of Study
This 5-year Capital Improvement Plan (CIP) is a study prepared by Finley Engineering Company, Inc. (Finley) based on an analysis and review of the historical system growth and operation to determine projections of future growth, recommendations for capital improvements, and scheduled system maintenance that will insure the continued economical and reliable operation of the system over the ensuing 5-year period.

5.1.3 – General Conclusions and Recommendations
The 5-Year CIP includes projects and estimated costs for Overhead Maintenance, Capital Maintenance, and Distribution System Improvements.

The Overhead Maintenance program include the inspection of 3,900 poles and the replacement of 350 pole at a total estimated cost of $4,058,438.

Capital Maintenance includes 18 various projects such as underground conductor replacement, fiber extensions, substation breaker upgrades, fire mitigation, line hardening, line re-routes and/or relocation, recloser installations for sectionalizing, etc. The total estimated cost for these projects 5-5
19248

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
is $20,784,500. It is expected that BEU will receive $9,293,750 in cost in aid to construction (CIAC) bringing the total BEU funding cost to $11,490,750.

Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include 14 projects to switch load to adjacent lines to reduce single-phase line loading at a total estimated cost of $41,700, 2 projects for new line construction of 600’ totaling $336,400, 9 projects for singlephase to three-phase line rebuild of 10,107’ totaling $2,142,100, and 2 projects for three-phase line rebuild using larger conductor of 2,130’ totaling $285,500. The total estimated cost for distribution system improvements is $2,805,700.

The total estimated cost for the 5-Year CIP is $27,648,638 with an estimated $9,293,750 in CIAC reducing the BEU funding estimate to $18,354,888. For the BEU funding cost, 22% is for Overhead Maintenance, 63% is for Capital Maintenance, and 15% is for Distribution System improvements.
5-6
19349

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.2 – Planning Criteria

5.2.1 - Distribution System
The distribution projects contained in this 5-Year CIP are recommended based upon the following planning criteria.
a. With an assumed delivered voltage of 125 volts (1.041 per unit on a 120 volt base) during peak load conditions, the design minimum allowable voltage at the primary terminals of any distribution transformer shall be 118 volts (0.98 per unit on a 120 volt base). b. Voltage regulators and step transformers will be upgraded when projected peak loads exceed 85% of the device’s rating.
c. Sectionalizing devices will be upgraded when projected peak loads exceed 70% of the device’s continuous current rating.
d. Primary conductors on the 7.2/12.5 kV and below distribution system will be upgraded when projected peak loads exceed 60% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 60% of the conductor’s thermal rating
e. Primary conductors on the 34.5 kV sub-transmission system will be upgraded when projected peak loads exceed 90% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 90% of the conductor’s thermal rating
f. Single-phase primary voltage lines will be limited to 35 amps maximum loading. g. The power factor at the delivery point under peak loading conditions is desired to be no less than 95%. The off-peak power factor should preferably be maintained between 95% lagging and 95% leading. This criterion is subject to the cost of the installation of capacitors, switches, and controls vs. the cost of kilowatt (kW) loss reduction.

5.2.1.1 - Distribution System Design Criteria
The following design criteria was considered when determining projects contained in this 5-year CIP.
a. Feeder current balance will be maintained at plus or minus 20% of the average per phase loading during peak conditions. This criterion may be relaxed in areas where it could impose unnecessary or premature costs.
b. Conductor sizes will be economically sized but may be modified to conform to BEU’s standard conductor sizes.
c. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any load voltage or high conductor loading. 5-7
19450

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
d. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any high single-phase loading. For areas where there is no backfeed or load switch solution, additional conductors will be added to allow for phase balancing. e. Relocation of existing line sections will be considered where inaccessibility impedes the maintenance of line sections or jeopardizes the service or reliability of line sections.

5.2.2 – Substation
The substation projects contained in this 5-Year CIP are recommended based upon the following planning criteria.
a. Substation transformers will limited to 95% of the max kVA rating of the transformer. The following improvements will be considered in the event the load exceeds 95% of the max kVA rating:
a. Load switching to adjacent substations
b. Upgrade of existing transformer
c. Installation of an additional transformer in the existing substation d. Construction of a new substation

5.2.3 – Basis of Cost Estimates
The following tables for material and labor costs were used to determine total project costs. The costs were taken from actual prices provided by BEU as well as prices received by FEC from other sources.

Table 5.2.3-1 Conductor Material Cost
Conductor (price per foot)
OH Conductor UG Conductor
#2 Copper $1.31 1/0 AL, 15 kV $2.03
#2 ACSR $0.26 1/0 CU, 15 kV $10.98
#4 ACSR $0.15 1/0 CU, 35 kV $8.47
1/0 ACSR $0.30 4/0 CU $6.95
4/0 Copper $3.11 4/0 AL $4.97
4/0 ACSR $0.80 350 CU $7.53
336 ACSR $1.62 750 AL $13.38
Table 5.2.3-2 Pole Material Cost
Pole Price per unit Pole Price per unit
35' Douglas Fir, H2 $1,269.30 35’ Wood, Class 2 $1,067.38 40’ Wood, Class 2 $766.35
45' Douglas Fir, H2 $1,771.08 45’ Wood, Class 2 $953.80 50’ Wood, Class 2 $1,135.73
55' Douglas Fir, H2 $2,889.48 55’ Wood, Class 2 $918.72 60' Douglas Fir, H2 $2,945.89 60’ Wood, Class 2 $1,362.29 5-8
19551

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.2.3-3 Transformer Material Cost
Transformer Price per unit
10 kVA O.H. Transformer S-Type 7,200 $500.00
15 kVA 7,200, 120/240 DV S-Type $645.42
25 kVA 7,200, 120/240 DV S-Type $919.16
37 kVA 7,200, 120/240 DV S-Type $1,496.65
50 kVA 7,200 120/240 $3,992.05
75 kVA 3Ø 12,470/7,200 120/208 $6,023.22
300 kVA DV $8,583.61
750 kVA 3Ø 12,470/7,200 $14,626.30
1,000 kVA 3Ø 12,470/7,200 DV $10,809.48
2,500 kVA 3Ø 12,470/7,200 277/480 $34,539.92
25 kVA 1Ø 12,470/7,200 120/240 Pdmnt $3,685.34

37.5 kVA 1Ø 12,400/7,200 DV Pdmnt $1,988.01
75 kVA 1Ø 12,470/7,200 120/240 Pdmnt $7,110.42
300 kVA 3Ø 12,470/4,160 DV Pdmnt 208/120 $13,547.15
500 kVA 3Ø Pdmnt $10,442.65
1,500 kVA DV 3Ø Pdmnt 277/480 $31,037.04
Table 5.2.3-4 Framing Units Material Cost
Framing Unit Price per unit
A1.3P $75.32
A1.11P $493.46
A5.2G $286.41
A3.1 $78.74
A6.21 $1,080.29
G1.2 $317.41
G1.2 $1,318.96
A5.1 $195.12
A5.21 $888.35
(A4.1) $255.90
G1.3 $433.79
G1.3 $1,127.02
C1.11 $628.33
C1.81G $1,592.53
C1.11,A5.21 $1,516.68
C5.82G $3,472.80
C3.1 $208.96
C3.1,A5.1 $404.08
C3.1,A5.21 $1,097.31
C3.1, C5.1 $376.78
C5.1 $167.82
C5.1,A5.1 $362.94
C5.1,A5.21 $1,056.17
5-9
19652

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.2.3-5 Underground Material Cost
Material Price per unit
Light Duty Secondary Box $78.42
Light Duty Secondary Lid $83.43
4" PVC SCH 40 (per foot) $1.69
1/0 AL U/G (per foot) $4.75
Service Entrance Sleeve $0.45
Deadend Shoe Small $8.58
Power Solve (Pulling Lube) $58.98
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost Units
(hr.)
Unit Cost
(per hr.)
Utility Bed P/U 1 ton (Foreman) (2 hrs. per connection) 4 $27.78 2 Person Lift (Bucket Truck) 55' (2 hrs. per connection) 2 $51.68 4 Person Crew 4 $466.73
3 Person Crew (2 hours per connection) 4 $352.02
2 Person Crew 2 $237.31
Electrical Engineering Supervisor (0.5 hrs. per connection) 1 $125.98 Electric Service Planning Supervisor (0.5 hrs. per connection) 1 $127.97 GIS Technician (1 hr. per connection) 2 $59.21
For overhead line, project cost estimates are based on an average of construction 1 mile of line per month with average span lengths at 150’.

Table 5.2.3-7 Underground Construction Labor and Fleet Cost Labor Price per hr.
4 Person Line Crew $466.73
Powerline Crew Superintendent $135.93
Fleet Price per hr.

Dump Truck $55.98
Utility Bed P/U 1 ton (Foreman) (3) $27.78
Digger Derrick $48.77
Wire Puller $24.98
Reel Trailer $24.98
Backhoe $23.95
For underground line, project estimates are based on an average construction of 1 month to trench, lay conduit, pull wire and terminate, and backfill 300’.

Engineering (10%) and contingency (5%) were also added for each cost estimate. 5-10
19753

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.3 – System Forecast
The 5-year CIP demand forecast was prepared to project the summer and winter kW demand per substation area as well as the total system demand for the City of Banning for the 2025-2030 CIP period. The historical non-coincident substation demands as well as the historical coincident system demands were provided by BEU and used as the basis for the forecast. BEU also provided insight into new load additions that are in some sort of application or planning process and were used in the conceptual forecast.

Additional factors that were considered when reviewing the historical peaks include temporary load switching between substations, construction of new substations with permanent load switching, and removal and/or replacement of existing substations.

Along with new load additions, considerations were also made for the addition of EV chargers at new subdivision locations.

This forecast will be used to run voltage drop and load flow analysis to determine system improvements required to reliably serve the City of Banning existing consumers and allow for future consumer growth.

It is projected that the BEU system will reach a non-coincident peak of 79,004 kW in the summer of 2030 and 59,385 kW in the winter of 2030. It is also projected that the BEU system will reach a coincident peak of 63,576 kW in the summer of 2030 and 53,737 kW in the winter of 2030.

A separate conceptual forecast was created to include new load additions that are in some state of application or planning process. It is projected that the BEU system will reach a conceptual non-coincident peak of 86,777 kW in the summer of 2030 and 76,938 kW in the winter of 2030.

As part of the historical review, MWH purchases were also reviewed and a forecast was determined. It is projected that the BEU system will have an annual coincident purchase of 192,127 MWH’s by 2030.

A graphical representation of the individual substation demand forecast as well as the total system coincident demand, non-coincident demand, conceptual non-coincident demand and MWH purchases is included following this page.
5-11
19854

BANNING ELECTRIC UTILTIY
2026-2045 ESMP SYSTEM FORECAST
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 San Gorgonio Total
S 16,425 17,079 16,472 9,131 4,958 16,500 16,830 17,167 17,510 17,860 18,217 18,582 18,953 19,332 19,719 20,113 20,516 20,926 21,345 21,771 22,207 22,651 23,104 23,566 24,037 24,518 2.0% W 15,022 12,746 11,267 7,193 3,739 15,000 15,300 15,606 15,918 16,236 16,561 16,892 17,230 17,575 17,926 18,285 18,651 19,024 19,404 19,792 20,188 20,592 21,004 21,424 21,852 22,289 2.0% Cannabis Cultivation 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 Yoshinoya 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 S 16,425 17,079 16,472 9,131 4,958 19,748 20,078 20,415 20,758 21,108 21,465 21,830 22,201 22,580 22,967 23,361 23,764 24,174 24,593 25,019 25,455 25,899 26,352 26,814 27,285 27,766 1.7% W 15,022 12,746 11,267 7,193 3,739 18,248 18,548 18,854 19,166 19,484 19,809 20,140 20,478 20,823 21,174 21,533 21,899 22,272 22,652 23,040 23,436 23,840 24,252 24,672 25,100 25,537 1.7% Midway Total
S 13,541 13,649 14,272 17,082 15,786 15,052 15,458 15,876 16,304 16,745 17,197 17,661 18,138 18,628 19,131 19,647 20,178 20,722 21,282 21,856 22,447 23,053 23,675 24,314 24,971 25,645 2.7% W 10,384 9,247 7,788 6,868 10,715 9,663 9,924 10,192 10,467 10,750 11,040 11,338 11,644 11,958 12,281 12,613 12,953 13,303 13,662 14,031 14,410 14,799 15,199 15,609 16,031 16,463 2.7% Airport
S 365 370 360 32 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% W 389 389 280 23 22 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% 22nd Street
S 10,233 10,319 9,736 10,585 11,240 10,670 10,787 10,906 11,026 11,147 11,270 11,394 11,519 11,646 11,774 11,904 12,034 12,167 12,301 12,436 12,573 12,711 12,851 12,992 13,135 13,280 1.1% W 8,140 6,529 6,105 6,567 8,018 8,210 8,300 8,392 8,484 8,577 8,672 8,767 8,863 8,961 9,059 9,159 9,260 9,362 9,465 9,569 9,674 9,781 9,888 9,997 10,107 10,218 1.1% Stagecoach
S 0 0 0 6,634 8,040 6,700 6,834 6,971 7,110 7,252 7,397 7,545 7,696 7,850 8,007 8,167 8,331 8,497 8,667 8,841 9,017 9,198 9,382 9,569 9,761 9,956 2.0% W 0 0 0 3,616 7,955 3,800 3,876 3,954 4,033 4,113 4,196 4,279 4,365 4,452 4,541 4,632 4,725 4,819 4,916 5,014 5,114 5,217 5,321 5,427 5,536 5,647 2.0% Ivy
S 0 0 5,308 7,206 8,333 5,400 5,508 5,618 5,731 5,845 5,962 6,081 6,203 6,327 6,453 6,583 6,714 6,849 6,985 7,125 7,268 7,413 7,561 7,713 7,867 8,024 2.0% W 0 0 4,493 4,890 6,235 4,500 4,590 4,682 4,775 4,871 4,968 5,068 5,169 5,272 5,378 5,485 5,595 5,707 5,821 5,938 6,056 6,178 6,301 6,427 6,556 6,687 2.0% Morongo Health Clinic 0 0 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 S 0 0 5,308 7,206 8,333 5,400 5,508 6,254 6,367 6,481 6,598 6,717 6,839 6,963 7,089 7,219 7,350 7,485 7,621 7,761 7,904 8,049 8,197 8,349 8,503 8,660 2.4% W 0 0 4,493 4,890 6,235 4,500 4,590 5,318 5,411 5,507 5,604 5,704 5,805 5,908 6,014 6,121 6,231 6,343 6,457 6,574 6,692 6,814 6,937 7,063 7,192 7,323 2.5% Sunset
S 8,140 8,099 9,586 11,441 14,821 10,439 10,857 11,291 11,742 12,212 12,701 13,209 13,737 14,286 14,858 15,452 16,070 16,713 17,382 18,077 18,800 19,552 20,334 21,147 21,993 22,873 4.0% W 6,716 5,803 5,037 8,299 11,443 6,319 6,572 6,835 7,108 7,392 7,688 7,996 8,315 8,648 8,994 9,354 9,728 10,117 10,522 10,942 11,380 11,835 12,309 12,801 13,313 13,846 4.0% Crestwood Communities 432 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 Vista Robles KB homes 0 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 S 8,140 8,099 9,586 11,441 14,821 10,871 13,233 13,667 14,118 14,588 15,077 15,585 16,113 16,662 17,234 17,828 18,446 19,089 19,758 20,453 21,176 21,928 22,710 23,523 24,369 25,249 4.3% W 6,716 5,803 5,037 8,299 11,443 6,751 8,948 9,211 9,484 9,768 10,064 10,372 10,691 11,024 11,370 11,730 12,104 12,493 12,898 13,318 13,756 14,211 14,685 15,177 15,689 16,222 4.5% Alola
S 2,929 2,370 1,646 372 0000000000000000000000 0.0%
W 2,377 708 782 336 0000000000000000000000 0.0%
Banning Electric Utility Non-Coincident System Peak Forecast S 51,632 51,885 57,380 62,482 63,207 68,441 71,898 74,088 75,683 77,322 79,004 80,732 82,507 84,330 86,202 88,126 90,103 92,134 94,221 96,367 98,571 100,837 103,167 105,562 108,024 110,556 2.4% W 43,029 35,422 35,752 37,792 48,126 51,172 54,186 55,919 57,045 58,200 59,385 60,600 61,847 63,127 64,440 65,788 67,172 68,592 70,050 71,546 73,083 74,661 76,281 77,945 79,654 81,410 2.3% Banning Electric Utility System Coincident Forecast
S 51,197 49,751 52,667 51,096 55,143 56,467 57,822 59,210 60,631 62,086 63,576 65,102 66,664 68,264 69,902 71,580 73,298 75,057 76,858 78,703 80,592 82,526 84,507 86,535 88,612 90,738 2.4% W 40,752 25,776 34,719 32,262 46,883 47,962 49,065 50,193 51,348 52,529 53,737 54,973 56,237 57,530 58,854 60,207 61,592 63,009 64,458 65,940 67,457 69,009 70,596 72,219 73,881 75,580 2.3% Conceptual Banning Electric Utility System Coincident Forecast S 51,197 49,751 52,667 51,096 55,143 56,467 58,962 61,201 69,810 76,184 86,777 100,472 109,135 120,377 129,082 137,336 145,321 153,347 157,527 161,751 166,019 167,953 169,934 171,962 174,039 176,165 5.9% W 40,752 25,776 34,719 32,262 46,883 47,962 50,205 52,185 60,527 66,627 76,938 90,343 98,708 109,643 118,034 125,963 133,615 141,299 145,127 148,988 152,884 154,436 156,023 157,646 159,308 161,007 6.2% Bridge-Morongo Logistics 0000 1,031 1,991 2,858 3,344 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 Sunset Crossroads 0 0 0 2,712 2,712 6,967 10,213 10,561 13,639 14,439 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 Rancho San Gorgonio 0 0 0 3,888 7,776 11,664 15,552 19,440 23,328 27,216 31,104 34,992 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 Mission Heights 000000 2,379 4,758 7,137 9,516 11,895 14,274 16,653 19,032 21,411 23,790 23,790 23,790 23,790 23,790 23,790 First Hathaway Logistics 0 0 0 0 0 0 471 471 471 471 471 471 471 471 471 471 471 471 471 471 471 Banning Commerce Center 0 0 0 0 0 0 438 438 438 438 438 438 438 438 438 438 438 438 438 438 438 WEKA 007777777777777777777
Charles St. CDRE 0 0 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 KCB Towers 0 0 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 Pallet Yard 007777777777777777777
First Lincoln Logistics 0 0 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 Brown Strauss 0 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 Wyndam Micro Hotel 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 DR Horton 0 0 588 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 Atwell Large Retail 0 0 0 0 0 0 880 880 880 880 880 880 880 880 880 880 880 880 880 880 880 2025-2045
Annual
Growth Rate
Historical Forecast
Peak kW Demand
5-12
19955
.00

80.0060.0040.0020.00
120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY NON-COINCIDENT SYSTEM PEAK FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
5-13
20056
.00

90.0080.0070.0060.0050.0040.0030.0020.0010.00
100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
5-14
20157
.00

80.0060.0040.0020.00
200.00180.00160.00140.00120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

CONCEPTUAL BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

6.2% ANNUAL GROWTH
RATE

SUMMER-FORECAST

5.9% ANNUAL GROWTH
RATE
5-15
20258

BANNING ELECTRIC UTILITY
2026-2045 ESMP NON-COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 11,577 21.27 12,259 22.52 12,651 23.24 12,906 23.71 13,167 24.19 13,435 24.68 13,710 25.19 Feb 10,470 21.33 11,086 22.58 11,441 23.31 11,671 23.78 11,907 24.26 12,150 24.75 12,399 25.26 Mar 10,870 20.69 11,511 21.91 11,879 22.61 12,118 23.07 12,363 23.54 12,615 24.01 12,873 24.51 Apr 13,733 32.53 14,427 34.18 14,867 35.22 15,187 35.98 15,515 36.76 15,853 37.56 16,200 38.38 May 15,631 37.92 16,420 39.84 16,920 41.05 17,285 41.94 17,659 42.85 18,043 43.78 18,438 44.74 Jun 18,497 56.73 19,432 59.59 20,023 61.41 20,455 62.73 20,897 64.09 21,352 65.48 21,819 66.92 Jul 25,788 65.86 27,090 69.19 27,915 71.29 28,517 72.83 29,134 74.40 29,768 76.02 30,419 77.69 Aug 26,719 68.44 28,069 71.90 28,923 74.09 29,546 75.68 30,186 77.32 30,843 79.00 31,517 80.73 Sep 21,335 64.10 22,413 67.34 23,096 69.39 23,593 70.88 24,104 72.42 24,628 73.99 25,167 75.61 Oct 19,525 51.17 20,675 54.19 21,336 55.92 21,766 57.05 22,206 58.20 22,658 59.38 23,122 60.60 Nov 10,787 21.08 11,423 22.32 11,788 23.04 12,025 23.50 12,269 23.98 12,518 24.46 12,775 24.97 Dec 12,073 22.02 12,784 23.31 13,193 24.06 13,458 24.54 13,731 25.04 14,010 25.55 14,297 26.07 TOTAL: 197,005 207,588 214,032 218,526 223,138 227,873 232,734 Summer Peak (MW) 68.44 71.90 74.09 75.68 77.32 79.00 80.73 Winter Peak (MW) 51.17 54.19 55.92 57.05 58.20 59.38 60.60 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 13,992 25.71 14,282 26.24 14,579 26.79 14,884 27.35 15,197 27.92 15,518 28.51 15,848 29.12 Feb 12,654 25.78 12,916 26.31 13,184 26.86 13,460 27.42 13,743 28.00 14,034 28.59 14,332 29.20 Mar 13,138 25.01 13,410 25.53 13,689 26.06 13,975 26.60 14,269 27.16 14,571 27.74 14,880 28.33 Apr 16,556 39.22 16,922 40.09 17,297 40.98 17,683 41.89 18,080 42.83 18,488 43.80 18,907 44.79 May 18,843 45.72 19,259 46.73 19,687 47.77 20,126 48.83 20,578 49.93 21,042 51.05 21,518 52.21 Jun 22,299 68.39 22,791 69.90 23,297 71.45 23,817 73.04 24,352 74.68 24,901 76.37 25,465 78.10 Jul 31,087 79.39 31,774 81.15 32,480 82.95 33,205 84.80 33,950 86.70 34,715 88.66 35,501 90.67 Aug 32,210 82.51 32,922 84.33 33,653 86.20 34,404 88.13 35,176 90.10 35,969 92.13 36,783 94.22 Sep 25,720 77.27 26,288 78.98 26,872 80.74 27,472 82.54 28,088 84.39 28,721 86.29 29,372 88.25 Oct 23,598 61.85 24,086 63.13 24,587 64.44 25,102 65.79 25,630 67.17 26,171 68.59 26,728 70.05 Nov 13,038 25.48 13,307 26.01 13,584 26.55 13,868 27.10 14,160 27.67 14,459 28.26 14,767 28.86 Dec 14,591 26.61 14,893 27.16 15,203 27.73 15,521 28.31 15,847 28.90 16,182 29.51 16,526 30.14 TOTAL: 237,725 242,850 248,113 253,518 259,069 264,770 270,627 Summer Peak (MW) 82.51 84.33 86.20 88.13 90.10 92.13 94.22 Winter Peak (MW) 61.85 63.13 64.44 65.79 67.17 68.59 70.05 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 16,187 29.74 16,534 30.38 16,891 31.03 17,258 31.71 17,634 32.40 18,021 33.11 18,418 33.84 Feb 14,638 29.82 14,953 30.46 15,275 31.12 15,607 31.79 15,947 32.49 16,297 33.20 16,656 33.93 Mar 15,198 28.93 15,525 29.55 15,860 30.19 16,204 30.85 16,558 31.52 16,921 32.21 17,294 32.92 Apr 19,337 45.81 19,779 46.86 20,234 47.93 20,702 49.04 21,182 50.18 21,676 51.35 22,184 52.55 May 22,008 53.40 22,512 54.62 23,029 55.88 23,561 57.17 24,108 58.49 24,671 59.86 25,249 61.26 Jun 26,044 79.88 26,640 81.70 27,253 83.58 27,882 85.51 28,530 87.50 29,195 89.54 29,879 91.64 Jul 36,310 92.73 37,140 94.85 37,994 97.03 38,872 99.27 39,774 101.58 40,702 103.95 41,656 106.38 Aug 37,621 96.37 38,482 98.57 39,366 100.84 40,276 103.17 41,211 105.56 42,172 108.02 43,160 110.56 Sep 30,041 90.26 30,728 92.32 31,434 94.44 32,161 96.63 32,907 98.87 33,675 101.17 34,464 103.55 Oct 27,299 71.55 27,885 73.08 28,487 74.66 29,105 76.28 29,740 77.95 30,392 79.65 31,062 81.41 Nov 15,082 29.47 15,406 30.11 15,739 30.76 16,080 31.43 16,431 32.11 16,791 32.82 17,161 33.54 Dec 16,879 30.78 17,242 31.44 17,614 32.12 17,996 32.82 18,389 33.54 18,792 34.27 19,206 35.03 TOTAL: 276,644 282,826 289,178 295,705 302,412 309,305 316,390 Summer Peak (MW) 96.37 98.57 100.84 103.17 105.56 108.02 110.56 Winter Peak (MW) 71.55 73.08 74.66 76.28 77.95 79.65 81.41 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
5-16
20359

BANNING ELECTRIC UTILITY
2026-2045 ESMP COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,100 20.39 11,356 20.86 11,617 21.34 11,884 21.83 12,157 22.34 12,437 22.85 Feb 9,813 19.99 10,038 20.45 10,269 20.92 10,506 21.40 10,747 21.89 10,994 22.40 11,247 22.91 Mar 10,188 19.40 10,423 19.84 10,662 20.30 10,908 20.76 11,158 21.24 11,415 21.73 11,678 22.23 Apr 11,331 26.84 11,603 27.49 11,881 28.15 12,166 28.82 12,458 29.51 12,757 30.22 13,063 30.95 May 12,896 31.29 13,205 32.04 13,522 32.81 13,847 33.60 14,179 34.40 14,519 35.23 14,868 36.07 Jun 15,261 46.80 15,627 47.93 16,002 49.08 16,386 50.25 16,780 51.46 17,182 52.70 17,595 53.96 Jul 21,276 54.34 21,787 55.64 22,309 56.98 22,845 58.34 23,393 59.74 23,955 61.18 24,529 62.65 Aug 22,044 56.47 22,573 57.82 23,115 59.21 23,670 60.63 24,238 62.09 24,820 63.58 25,415 65.10 Sep 17,603 52.89 18,025 54.16 18,458 55.45 18,901 56.79 19,354 58.15 19,819 59.54 20,294 60.97 Oct 18,300 47.96 18,721 49.06 19,151 50.19 19,592 51.35 20,042 52.53 20,503 53.74 20,975 54.97 Nov 10,110 19.76 10,343 20.21 10,581 20.68 10,824 21.15 11,073 21.64 11,328 22.14 11,588 22.65 Dec 11,315 20.64 11,575 21.11 11,842 21.60 12,114 22.09 12,393 22.60 12,678 23.12 12,969 23.65 TOTAL: 170,987 175,020 179,149 183,374 187,700 192,127 196,659 Summer Peak (MW) 56.47 57.82 59.21 60.63 62.09 63.58 65.10 Winter Peak (MW) 47.96 49.06 50.19 51.35 52.53 53.74 54.97 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 12,723 23.38 13,016 23.91 13,315 24.46 13,621 25.03 13,935 25.60 14,255 26.19 14,583 26.79 Feb 11,506 23.44 11,771 23.98 12,041 24.53 12,318 25.09 12,602 25.67 12,891 26.26 13,188 26.86 Mar 11,946 22.74 12,221 23.26 12,502 23.80 12,790 24.35 13,084 24.91 13,385 25.48 13,693 26.07 Apr 13,377 31.69 13,698 32.45 14,027 33.23 14,363 34.03 14,708 34.84 15,061 35.68 15,422 36.54 May 15,225 36.94 15,590 37.83 15,964 38.73 16,347 39.66 16,740 40.62 17,142 41.59 17,553 42.59 Jun 18,017 55.26 18,449 56.58 18,892 57.94 19,346 59.33 19,810 60.75 20,285 62.21 20,772 63.71 Jul 25,118 64.15 25,721 65.69 26,338 67.27 26,970 68.88 27,618 70.53 28,281 72.23 28,959 73.96 Aug 26,025 66.66 26,650 68.26 27,289 69.90 27,944 71.58 28,615 73.30 29,302 75.06 30,005 76.86 Sep 20,781 62.44 21,280 63.94 21,791 65.47 22,314 67.04 22,849 68.65 23,398 70.30 23,959 71.98 Oct 21,457 56.24 21,951 57.53 22,456 58.85 22,972 60.21 23,501 61.59 24,041 63.01 24,594 64.46 Nov 11,855 23.17 12,128 23.70 12,406 24.25 12,692 24.80 12,984 25.37 13,282 25.96 13,588 26.55 Dec 13,268 24.20 13,573 24.75 13,885 25.32 14,204 25.90 14,531 26.50 14,865 27.11 15,207 27.73 TOTAL: 201,298 206,047 210,907 215,882 220,975 226,188 231,523 Summer Peak (MW) 66.66 68.26 69.90 71.58 73.30 75.06 76.86 Winter Peak (MW) 56.24 57.53 58.85 60.21 61.59 63.01 64.46 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 14,918 27.41 15,261 28.04 15,612 28.68 15,971 29.34 16,339 30.02 16,715 30.71 17,099 31.42 Feb 13,491 27.48 13,801 28.11 14,119 28.76 14,444 29.42 14,776 30.10 15,116 30.79 15,463 31.50 Mar 14,007 26.67 14,330 27.28 14,659 27.91 14,996 28.55 15,341 29.20 15,694 29.88 16,055 30.56 Apr 15,793 37.41 16,172 38.31 16,560 39.23 16,957 40.17 17,364 41.14 17,781 42.12 18,208 43.13 May 17,974 43.61 18,406 44.66 18,847 45.73 19,300 46.83 19,763 47.95 20,237 49.10 20,723 50.28 Jun 21,271 65.23 21,781 66.80 22,304 68.40 22,839 70.04 23,387 71.73 23,949 73.45 24,523 75.21 Jul 29,654 75.73 30,366 77.55 31,095 79.41 31,841 81.32 32,605 83.27 33,388 85.27 34,189 87.32 Aug 30,725 78.70 31,462 80.59 32,218 82.53 32,991 84.51 33,783 86.53 34,593 88.61 35,424 90.74 Sep 24,534 73.71 25,123 75.48 25,726 77.29 26,344 79.15 26,976 81.05 27,623 82.99 28,286 84.98 Oct 25,160 65.94 25,738 67.46 26,330 69.01 26,936 70.60 27,555 72.22 28,189 73.88 28,838 75.58 Nov 13,900 27.17 14,220 27.79 14,547 28.43 14,882 29.08 15,224 29.75 15,574 30.44 15,932 31.14 Dec 15,557 28.37 15,915 29.02 16,281 29.69 16,655 30.37 17,038 31.07 17,430 31.79 17,831 32.52 TOTAL: 236,985 242,576 248,298 254,156 260,152 266,289 272,571 Summer Peak (MW) 78.70 80.59 82.53 84.51 86.53 88.61 90.74 Winter Peak (MW) 65.94 67.46 69.01 70.60 72.22 73.88 75.58 Projected Load Data 2039-2045
Projected Load Data 2032-2038
2039 2040 2041 2042 2043 2044 2045
Projected Load Data 2025 - 2031
2032 2033 2034 2035 2036 2037 2038
2025 2026 2027 2028 2029 2030 2031
5-17
20460

BANNING ELECTRIC UTILITY
2026-2045 ESMP CONCEPTUAL COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,358 20.87 11,806 21.69 13,693 25.16 15,074 27.69 17,406 31.98 20,439 37.55 Feb 9,813 19.99 10,272 20.92 10,677 21.75 12,384 25.23 13,632 27.77 15,741 32.07 18,484 37.65 Mar 10,188 19.40 10,665 20.30 11,085 21.10 12,857 24.48 14,153 26.94 16,344 31.11 19,191 36.53 Apr 11,331 26.84 11,831 28.03 12,281 29.09 14,008 33.19 15,287 36.22 17,413 41.25 20,161 47.76 May 12,896 31.29 13,466 32.67 13,977 33.91 15,943 38.68 17,399 42.22 19,818 48.08 22,946 55.67 Jun 15,261 46.80 15,935 48.87 16,540 50.73 18,867 57.86 20,590 63.15 23,453 71.93 27,154 83.28 Jul 21,276 54.34 22,216 56.74 23,060 58.89 26,303 67.18 28,705 73.31 32,696 83.50 37,856 96.68 Aug 22,044 56.47 23,018 58.96 23,892 61.20 27,253 69.81 29,742 76.18 33,877 86.78 39,223 100.47 Sep 17,603 52.89 18,380 55.22 19,078 57.32 21,762 65.38 23,749 71.35 27,051 81.27 31,320 94.10 Oct 18,300 47.96 19,156 50.20 19,911 52.18 23,094 60.53 25,421 66.63 29,356 76.94 34,470 90.34 Nov 10,110 19.76 10,583 20.68 11,001 21.50 12,759 24.94 14,045 27.45 16,219 31.70 19,044 37.22 Dec 11,315 20.64 11,844 21.60 12,312 22.45 14,280 26.04 15,719 28.67 18,151 33.10 21,314 38.87 TOTAL: 170,987 178,725 185,621 213,204 233,515 267,525 311,603 Summer Peak (MW) 56.47 58.96 61.20 69.81 76.18 86.78 100.47 Winter Peak (MW) 47.96 50.20 52.18 60.53 66.63 76.94 90.34 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 22,332 41.03 24,806 45.58 26,704 49.06 28,498 52.36 30,229 55.54 31,967 58.73 32,833 60.32 Feb 20,195 41.14 22,433 45.70 24,149 49.19 25,772 52.50 27,337 55.69 28,909 58.89 29,692 60.49 Mar 20,968 39.92 23,291 44.34 25,073 47.73 26,758 50.94 28,383 54.03 30,016 57.14 30,829 58.69 Apr 21,899 51.88 24,155 57.22 25,902 61.36 27,558 65.29 29,160 69.08 30,771 72.90 31,610 74.88 May 24,924 60.47 27,492 66.70 29,480 71.53 31,365 76.10 33,188 80.53 35,021 84.97 35,976 87.29 Jun 29,495 90.46 32,534 99.78 34,886 106.99 37,117 113.83 39,275 120.45 41,444 127.10 42,574 130.57 Jul 41,121 105.02 45,356 115.84 48,637 124.21 51,746 132.15 54,755 139.84 57,779 147.56 59,354 151.58 Aug 42,606 109.14 46,994 120.38 50,393 129.08 53,615 137.34 56,732 145.32 59,866 153.35 61,498 157.53 Sep 34,021 102.21 37,526 112.74 40,239 120.90 42,812 128.63 45,301 136.11 47,803 143.62 49,107 147.54 Oct 37,662 98.71 41,835 109.64 45,036 118.03 48,061 125.96 50,981 133.62 53,913 141.30 55,373 145.13 Nov 20,808 40.66 23,113 45.17 24,882 48.63 26,553 51.89 28,166 55.05 29,786 58.21 30,593 59.79 Dec 23,287 42.47 25,867 47.17 27,847 50.78 29,718 54.20 31,523 57.49 33,336 60.79 34,239 62.44 TOTAL: 339,319 375,401 403,228 429,573 455,032 480,611 493,678 Summer Peak (MW) 109.14 120.38 129.08 137.34 145.32 153.35 157.53 Winter Peak (MW) 98.71 109.64 118.03 125.96 133.62 141.30 145.13 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 33,707 61.93 34,588 63.55 34,939 64.19 35,298 64.85 35,666 65.53 36,042 66.22 36,426 66.93 Feb 30,483 62.10 31,280 63.72 31,597 64.37 31,922 65.03 32,254 65.70 32,594 66.40 32,941 67.10 Mar 31,649 60.25 32,477 61.82 32,806 62.45 33,143 63.09 33,488 63.75 33,841 64.42 34,202 65.11 Apr 32,457 76.89 33,314 78.92 33,702 79.84 34,099 80.78 34,506 81.75 34,923 82.73 35,350 83.74 May 36,941 89.63 37,915 91.99 38,357 93.07 38,810 94.16 39,273 95.29 39,747 96.44 40,233 97.62 Jun 43,716 134.07 44,869 137.61 45,392 139.21 45,927 140.85 46,475 142.53 47,037 144.25 47,611 146.02 Jul 60,946 155.65 62,554 159.76 63,283 161.62 64,029 163.52 64,793 165.47 65,575 167.47 66,377 169.52 Aug 63,146 161.75 64,813 166.02 65,568 167.95 66,341 169.93 67,133 171.96 67,943 174.04 68,774 176.17 Sep 50,423 151.49 51,754 155.49 52,357 157.30 52,974 159.16 53,606 161.06 54,254 163.00 54,917 164.99 Oct 56,847 148.99 58,333 152.88 58,925 154.44 59,531 156.02 60,150 157.65 60,784 159.31 61,432 161.01 Nov 31,407 61.38 32,228 62.98 32,555 63.62 32,890 64.28 33,232 64.95 33,582 65.63 33,941 66.33 Dec 35,150 64.10 36,069 65.78 36,435 66.45 36,809 67.13 37,192 67.83 37,584 68.54 37,985 69.27 TOTAL: 506,871 520,193 525,915 531,773 537,769 543,906 550,188 Summer Peak (MW) 161.75 166.02 167.95 169.93 171.96 174.04 176.17 Winter Peak (MW) 148.99 152.88 154.44 156.02 157.65 159.31 161.01 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
5-18
20561
0 50
300250200150100
'19 '20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MWH (x1,000)
YEAR

BANNING ELECTRIC UTILTIY MWH PURCHASES

HISTORICAL

FORECAST

2.4% ANNUAL GROWTH
RATE
5-19
20662
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SAN GORGONIO TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.7% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.7% ANNUAL GROWTH
RATE
5-20
20763
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
MIDWAY TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

SUMMER-FORECAST

2.7% ANNUAL GROWTH
RATE

WINTER-FORECAST

2.7% ANNUAL GROWTH
RATE
5-21
20864
0 8,0006,0004,0002,000
14,00012,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
22ND STREET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.1% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.1% ANNUAL GROWTH
RATE
5-22
20965
0 8,0006,0004,0002,000
12,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
STAGECOACH kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
5-23
21066
0 9,0008,0007,0006,0005,0004,0003,0002,0001,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
IVY kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
5-24
21167
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SUNSET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

4.5% ANNUAL GROWTH
RATE

SUMMER-FORECAST

4.3% ANNUAL GROWTH
RATE
5-25
21268

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.4 – Overhead Maintenance Program
The Overhead Maintenance Program include the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect 15 poles per week for the years 2026 thru 2030. This totals to 780 poles inspected per year and 3,900 poles inspected for the duration of the 5-Year CIP. An estimated cost of $270 per pole inspection was used and a 3% inflation to this cost was assumed per year starting in 2027. The total estimated cost for pole inspections for the 5-Year CIP is $1,151,647.

It is projected that BEU will replace 50 poles per year for the years 2026 thru 2028 and 100 poles per year for the years 2029 and 2030. This totals to 350 poles replaced for the duration of the 5- Year CIP. An estimated cost of $7,520 per pole replacement was used and a 3% inflation to this cost was assumed per year starting in 2027. The total estimated cost for pole replacements for the 5-Year CIP is $2,906,791.

The total estimated cost for the Overhead Maintenance Program for the 5-year CIP is $4,058,438.

The table below shows a breakdown of the Overhead Maintenance Program.

Table 5.4-1 – Overhead Maintenance Program Costs
2026 2027 2028 2029 2030 Total
Number of Poles
Inspected 780 780 780 780 780 3,900
Cost per
Inspection 278 286 295 304 313 -
Total Cost of
Inspection $216,918 $223,426 $230,128 $237,032 $244,143 $1,151,647 Number of Poles
Replaced 50 50 50 100 100 350
Cost per
Replacement $7,746 $7,978 $8,217 $8,422 $8,675 -
Total Cost of
Replacement $387,280 $398,898 $410,865 $842,240 $867,507 $2,906,791 Total Overhead
Maintenance
Program
$604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 5-26
21369

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.5 – Capital Maintenance Projects
BEU has identified 18 Capital Maintenance projects to include in the 5-year CIP. The total estimated cost for these projects is $20,784,500. It is projected that BEU will receive $9,293,750 in contributions in aid to these projects bringing the total BEU funding cost to $11,490,750.

The following tables list the Capital Maintenance projects that have been identified for inclusion to the 5-year CIP.

Table 5.5-1 – Capital Maintenance Project Costs
Project Description Year Total Cost CIAC
BEU
Funding
Cost
Underground Conversion Livingston to
Hargrave (Backbone/Fiber loop at
Ramsey/Livingston/Alola)
2027-
2028 $149,500 $0 $149,500
Underground Conductor Replacement
Barbour St E/O Hathaway 2027 $275,000 $0 $275,000
Underground Conductor Replacement at
Mockingbird Lane and Hillside Dr 2027 $750,000 $0 $750,000 Underground Conductor Replacement at
Westward Ave from 4th St to 8th St 2027 $625,000 $0 $625,000 Fiber Extension to Stagecoach
Substation (UG and OH) 2027 $285,000 $0 $285,000
Midway Substation Upgrades (breaker
replacement and SCADA-ready
upgrades and future full replacement)
2027-
2030 $6,125,000 $0 $6,125,000

34.5 kV/12.47 kV (Cir 77)/fiber UG and
OH Extension to Sunset Ave 2029 $2,000,0001 $1,200,000 $800,000 SoCalGas Reimbursement for Feeder
Circuits to Cottonwood Ave 2027 TBD 100% $0
1 Up to 60% contribution from WKJ Development
5-27
21470

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.5-1 – Capital Maintenance Project Costs (continued) Project Description Year Total Cost CIAC
BEU
Funding
Cost
Underground Conductor Replacement
at Vista Serena Ave 2029 $350,000 $175,0002 $175,000
Fire Mitigation Tier 2/3 High Threat Area
(Various)
2026-
2028 $450,000 $0 $450,000
Mias Canyon Line Hardening 2027 $2,100,000 $2,100,0003 $0

34.5 kV/12.47 kV/fiber Underground
Circuits Hathaway St from Williams St
to Hoffer St
2029-
2030 $2,000,000 $2,000,0004 $0

34.5 kV/12.47 kV/fiber Underground
Circuits Lincoln St to John St
2027,
2029 $150,000 $0 $150,000
Install Two (2) Engineered base-plate
pole at Sunset and Lincoln
2028-
2029 $850,000 $0 $850,000
Install Reclosers on 34.5 kV and 12.47
kV system 2028 $250,000 $0 $250,000
Robertson's Ready Mix Circuit Re-route 2026-
2028 $425,000 $318,7505 $106,250
Sun Lakes Blvd Extension - Electric
Relocation
2026-
2028 $3,500,000 $3,500,0006 $0
2 Up to 50% contribution from Vista Serena Developer
3 100% grant funded
4 100% funded from Sansone Group and First Hathaway Industrial 5 Up to 75% contribution from Robertson’s Ready Mix
6 100% Public Works funded
5-28
21571

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.5-1 – Capital Maintenance Project Costs (continued) Project Description Year Total Cost CIAC
BEU
Funding
Cost
SCE Upfront Capital Costs 2028 $500,000 $0 $500,000
$20,784,500 $9,293,750 $11,490,750
The following pages contain the CIP worksheets as provided by BEU. 5-29
21672

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$149,500 $9,500 $140,000
$149,500 $9,500 $140,000 $0 $0 $0 $0
Engineering
Project Title:

Complete distribution circuit ties between San Gorgonio Substation and Stagecoach Substation that will provide electric distribution to the area that had been previously served by the decommissioned Alola Substation. This project will include short distance line extensions, installation of PME switches, and fiber optic cable installation.

Estimated Completion Date:

Underground Conversion Livingston to Hargrave (Backbone/Fiber loop at Ramsey/Livingston/Alola ) 12/1/2027
Project Description:

Provides added redundancy and resiliency to distribution service in the northeast section of BEU's service territory.

Project Status: Photo/Exhibit/Vicinity Map
Currently in design; construction phase is tentatively scheduled to commence construction during FY 26/27 and will conclude in FY 27/28.

Budget Distribution Est. Amount
$9,500
$0
$0
$5,000
$135,000
$149,500
Electric Revenue $149,500
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $149,500
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-30
73 217

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$275,000 $275,000
$275,000 $275,000 $0 $0 $0 $0 $0
Engineering
Brandon Robinson, Electric Engineering Supervisor
Project Description:

Complete 12.47kV conversion for four service at 700 S. Hathaway St. Decommission Airport Substation.

Funding Plan:

Division: Contacts:
$0
$0
$275,000
Department:

Electric Fred Lyn, Deputy Electric Utility Director
Total
Project Title: Estimated Completion Date:

Funding Source Total
$275,000
This project will conclude the 12kV Conversion project that has taken BEU nearly 50 years to complete. This will provide stable service reliability in the area.

Est. Amount
Photo/Exhibit/Vicinity Map Project Status:

Currently in design; construction phase is tentatively scheduled to commence construction during FY 26/27.

Underground Conversion Barbour St (12kV Conversion at 700 S. Hathaway) 12/1/2026 Budget Distribution
Electric Revenue
$275,000
$20,000
$0
$0
$5,000
$250,000
5-31
74 218

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$750,000 $750,000
$750,000 $750,000 $0 $0 $0 $0 $0
Engineering
Project Title:

Complete reconductoring on Hillside Dr and Mockingbird Ln.

Estimated Completion Date:

Underground Conductor Replacement - Mockingbird & Hillside 12/1/2026 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
The initial phase of this project was completed in 2023 due to the occurrence of a fault on an unjacketed primary distribution conductor within the project area; the final phase of construction phase is tentatively scheduled to commence during FY 26/27.

Budget Distribution Est. Amount
$55,000
$0
$0
$18,000
$677,000
$750,000
Electric Revenue $750,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $750,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-32
75 219

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$625,000 $625,000
$625,000 $625,000 $0 $0 $0 $0 $0
Engineering
Project Title:

Complete reconductoring on between Westward Ave and Barbour St, from 4th St to 8th St.

Estimated Completion Date:

Underground Conductor Replacement - Westward Ave to Barbour St, 4th St to 8th St 6/1/2026 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
Some preliminary reconductoring occurred during a 2022 fault event involving unjacketed primary distribution conductor within the project area; construction of all improvements is tentatively scheduled to commence during FY 26/27.

Budget Distribution Est. Amount
$25,000
$0
$0
$10,000
$590,000
$625,000
Electric Revenue $625,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $625,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-33
76 220

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$285,000 $285,000
$0
$285,000 $285,000 $0 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $285,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $285,000
CIAC $0
Funding Source Total
This project will help push BEU toward completion of fiber optic hard line connectivity all six substations for SCADA monitoring and control.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
In 2022, BEU completed a line extension on Hargrave Street from the site of the decommissioned Alola Substation to the newly built Stagecoach Substation in order to energize the asset and provide service to the northeast portion of BEU's service area.

The design for this pole line extension included provisions for a future utility fiber optic line attachment to support SCADA communication. BEU anticipates construction to commence during FY 26/27, but may be able to be delayed and encumbered into future fiscal year budgets if needed.

Budget Distribution Est. Amount
$15,000
$0
$0
$5,000
$265,000
$285,000
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits thru easement within Banning Airport property from Lincoln St to John St.

Estimated Completion Date:

Fiber Extension to Stagecoach 12/30/2027
Project Description:
5-34
77 221

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$125,000 $75,000 $50,000
$125,000 $75,000 $50,000 $0 $0 $0 $0
Engineering
Project Title:

Install SCADA RTU and other equipment to make Midway Substation SCADA ready. Replace distribution with spare breakers as needed. This project will also address potential full substation upgrade if direction is to utilize the existing property.

Estimated Completion Date:

Midway Substation Upgrades (breaker replacement and SCADA upgrades) 5/30/2028 Project Description:

Midway is BEU's oldest Substation, built in 1972. Most of the equipment, including the transformers and distribution breakers are original and nearing the end of useful life. The SCADA upgrades will allow remote visibility at the substation, while as-needed breaker replacement will allow the substation to continue operating as intended. The eventual replacement of all equipment at the substation will help conclude modernization of all BEU's substation assets.

Project Status: Photo/Exhibit/Vicinity Map
BEU has began vetting equipment that will be utilized to make Midway Substation SCADA-ready. Construction of this phase is tentatively scheduled to commence during FY 26/27. All other improvements we be evaluated later in the initial 5-yr CIP period.

Budget Distribution Est. Amount
$5,000
$0
$0
$2,500
$117,500
$125,000
Electric Revenue $125,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $125,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-35
78 222

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$800,000 $800,000
$1,200,000 $1,200,000
$2,000,000 $0 $0 $2,000,000 $0 $0 $0
Engineering
Project Title:

Extend electric sub-transmission and distribution from Mountain Ave to Sunset Ave.

Estimated Completion Date:

34.5kV/12.47kV (Cir 77)/fiber UG and OH Extension to Sunset Ave 6/30/2029 Project Description:

Circuit #77, which originates from Sunset Substation, is terminated in a switch cabinet on Mountain Ave. This circuit was designed to provide distribution services to newer developments along Sunset Ave north of Wilson St. Completing this line extension allows BEU to fulfill this need, while also seeking monetary contributions from these developments thru line extension agreements.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed a preliminary design of the 12.47kV distribution extension thru the area. Design for the 34.5kV and fiber extension still needs to be completed.

Environmental, survey, and possible ROW acquisition will be required for this project.

Construction is tentatively scheduled to commence during FY 28/29, or as soon as advance on construction is received for from developers in the area that will be served with this line extension.

Budget Distribution Est. Amount
$115,000
$50,000
$75,000
$45,000
$1,715,000
$2,000,000
Electric Revenue $800,000
CIAC (WJK Development) $1,200,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $2,000,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-36
79 223

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$175,000 $175,000
$175,000 $175,000
$350,000 $175,000 $0 $175,000 $0 $0 $0
Engineering
Project Title:

Complete reconductoring of unjacketed cable in the Vista Serena development in conjunction with an ongoing development-driven project to complete buildout of the complex.

Estimated Completion Date:

Underground Conductor Replacement at Vista Serena 6/30/2029 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed minor reconductoring within Vista Serena that had come as a result of outages created by cable fault/failure. Design for the complete distribution upgrades to serve the development is in progress. The developer will have a cost responsibility for new line extensions within the development, as well as replacement of some of the existing unjacketed cable. Construction is tentatively scheduled to commence during FY 26/27, or as soon as advance on construction is received from the developer.

Completion of all remaining reconductoring outside of developer requirements will occur during FY 28/29.

Budget Distribution Est. Amount
$6,500
$0
$0
$15,000
$328,500
$350,000
Electric Revenue $175,000
CIAC (Vista Serena) $175,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $350,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-37
80 224

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$450,000 $150,000 $150,000 $150,000
$0
$450,000 $150,000 $150,000 $150,000 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $450,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $450,000
CIAC $0
Funding Source Total
This project will assist with the continued monitoring and operation of the electric distribution facilities within the HFTD Tiers 2 & 3 areas. The California Public Utility Commission's Wildfire Safety Advisory Board (WSAB) recommended that utilities with electric transmission or distribution facilities in HFTDs make tangible improvements to the monitoring and operation of these facilities to reduce wildfire risk.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
BEU has been required to submit a Wildfire Mitigation Plan for review to the WSAB each year since 2020. Within this time, BEU has completed minor improvements to facilities in Banning Canyon (water canyon) and has applied for grant funding to upgrade facilities within Mias Canyon. BEU is obligated to continue fire mitigation efforts, and has identified the use of reclosers as a high priority solution for circuits that enter the HFTD. BEU anticipates construction to begin during FY 26/27, and continue annually until grid hardening solutions have been met. BEU will continue to search for and apply for grant funding to offset revenue expenditures.

Budget Distribution Est. Amount
$25,000
$0
$0
$5,000
$420,000
$450,000
Project Title:

BEU will complete improvements to control of electricity in the Tiers 2 & 3 High Fire Threat District (HFTD). BEU will begin with the installation of distribution circuit reclosers to allow power to be shut off to these areas in the event that an imminent threat to public safety becomes present.

Estimated Completion Date:

Fire Mitigation Improvements in High Fire Threat District 6/30/2029 Project Description:
5-38
81 225

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$0
$2,100,000 $2,100,000
$2,100,000 $2,100,000 $0 $0 $0 $0 $0
Engineering
$2,100,000
$45,000
$1,860,000
Funding Plan:

Funding Source Total
Electric Revenue $0
CIAC (Grant)
Brandon Robinson, Electric Engineering Supervisor
Total $2,100,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Project Status:

Photo/Exhibit/Vicinity Map
The result from the Apple Fire in 2020 prompted BUE to search for funding to complete much needed upgrades/line hardening in areas within the service territory that are most susceptible to fire ignition. BEU began the design and grant application process for this project in 2021, and is currently awaiting funding after various design and environmental clearance activities. This project will be grant-funded thru the federal government's Hazard Mitigation Grant Program at 75% of total project cost, with 25% matching contributions form California Governor's Office of Emergency Services (CalOES) to complete the full 100% funding. Construction start for this project is dependent upon the grant funding during FY 26/27, in which BEU will be given 24 months to complete.

Budget Distribution Est. Amount
$185,000
$0
$10,000
$2,100,000
Project Title:

This project involves replacing 75 utility poles with new fire retardant-treated poles; replacing wooden crossarms on poles with fiberglass crossarms; installing insulated/covered wire and jumpers; installing covered insulators; installing line protection measures; and completing hazardous fuels reduction.

This project will help provide redundancy on our 34.5kV and 12.47kV and assist providing a point of connection to the 34.5kV system for the proposed substation to support expansion in the eastern part of the City.

Estimated Completion Date:

Mias Canyon Line Hardening 12/30/2028
Project Description:
5-39
82 226

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$2,000,000 $1,000,000 $1,000,000
$2,000,000 $0 $0 $1,000,000 $1,000,000 $0 $0
Engineering
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits on Hathaway St and new utility service extensions to accomodate new industrial development.

This project is fully dependent on the completion of this development.

Estimated Completion Date:

34.5kV/12.47kV/fiber Underground Circuits Hathaway St from Williams St to Hoffer St 6/30/2030 Project Description:

This project will accommodate street improvements required by the Sansone Group and First Hathaway Industrial warehouse developments. This will also assist with beautification of the eastern corridor due to the undergrounding of BEU utilities.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed UG conversion of facilities from Ramsey St to Williams St along Hathaway St in 2022. Design for this project is in progress. The developers will have a full responsibility for relocation/conversion along Hathaway St and new line extensions within the development. Construction is tentatively scheduled to commence during FY 28/29, or as soon as advance on construction is received from the developer.

Budget Distribution Est. Amount
$55,000
$0
$0
$35,000
$1,910,000
$2,000,000
Electric Revenue $0
CIAC (Sansone/First Hathaway) $2,000,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $2,000,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-40
83 227

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$175,000 $20,000 $130,000
$0
$175,000 $20,000 $0 $130,000 $0 $0 $0
Engineering
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits thru easement within Banning Airport property from Lincoln St to John St.

Estimated Completion Date:

34.5kV/12.47kV/fiber Underground Circuits Lincoln St to John St 6/30/2029 Project Description:

This project will help provide redundancy on our 34.5kV and 12.47kV and assist providing a point of connection to the 34.5kV system for the proposed substation to support expansion in the eastern part of the City.

Project Status: Photo/Exhibit/Vicinity Map
In 2015, BEU completed a line extension thru an existing utility easement on the airport property to accommodate future redundancy needs. BEU has also completed UG line extensions to new facilities in the area which began in 2021. As the City continues to build out, more capacity will be needed in East Banning. Design for this project should begin early 2027. There may be a design/construction cost responsibility for future developers, but that cost is still unknown. BEU anticipates construction to commence during FY 28/29, as the need for additional capacity may become a requirement.

Budget Distribution Est. Amount
$20,000
$0
$0
$5,000
$125,000
$150,000
Electric Revenue $150,000
CIAC $0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $150,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-41
84 228

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$850,000 $425,000 $425,000
$0
$850,000 $0 $425,000 $425,000 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $850,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $850,000
CIAC $0
Funding Source Total
This project will provide a much needed infrastructure upgrade for a critical 69/34.5kV/12.47kV/fiber pole line that contains the capacity to support 2/3 of BEU's total energy demand. This pole line carries transmission to Midway and Subset Substations which account for the largest loads within BEU's service territory.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
In 2014, BEU completed a relocation of the steel pole transmission line at Sunset Ave and Lincoln Street. The final phase of this project was to be completed prior to 2017, however budget constraints prevented the completion of the project. There may be a design/construction cost responsibility for future developers, but that cost is still unknown. BEU anticipates construction to commence during FY 28/29, which is anticipated to coincide with commercial development within the area.

Budget Distribution Est. Amount
$60,000
$0
$50,000
$35,000
$705,000
$850,000
Project Title:

Installation of two engineer-base steel pole to support 69/ 34.5kV, 12.47kV and fiber optic circuits on the west side of Sunset Ave north of Lincoln St.

Estimated Completion Date:

Engineered Base-Plate Poles at Sunset and Lincoln 6/30/2029 Project Description:
5-42
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CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$250,000 $250,000
$250,000 $0 $250,000 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $250,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $250,000
CIAC (Grant) $0
Funding Source Total
This project will allow BEU to improve redundancy and reliability within the system by isolating outages to a smaller area and reduce power restoration times.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
Planning and equipment research for this project began in 2022 and will continue with the completion of a system impact study of the current electric grid. BEU will vet different equipment manufacturers and determine the best method for initiating the pilot. The project will be constructed using BEU's in-house power line construction services. The pilot will include investigation and implementation of distribution automation (DA) solutions to provide communication with the field devices that are installed. BEU anticipates this pilot to begin in FY 27/28.

Budget Distribution Est. Amount
$35,000
$0
$0
$5,000
$210,000
$250,000
Project Title:

BEU will complete a pilot project to install reclosers and other sectionalizing devices on the distribution and sub-transmission system.

Estimated Completion Date:

Install Reclosers on 34.5 kV and 12.47 kV system 6/30/2028 Project Description:
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CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$106,250 $106,250
$318,750 $318,750
$425,000 $318,750 $106,250 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $425,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $106,250
CIAC $318,750
Funding Source Total
This project will be required to rebuild BEU's distribution circuit around Robertson's Ready Mix's expanded mining site that was previously removed. BEU will regain the loss in capacity and redundancy in the system be completing this circuit re-build.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
BEU is negotiating a line extension agreement with Roberston's Ready Mix to complete the circuit re-route around the expanded mining area north of Hoffer St and west of Hathaway St. BEU has already completed removal of utility poles in conflict with the new mining activities in anticipation of beginning the construction of the circuit re-rout by 2025. There will be a design/construction cost responsibility for Robertson's that will total 75% or more of total project costs. BEU anticipates construction to commence during FY 26/27 and be completed in the following fiscal year.

Budget Distribution Est. Amount
$65,000
$0
$0
$15,000
$345,000
$425,000
Project Title:

Re-route/rebuild of 34.5kV, 12.47kV and fiber optic circuits around the Robertson's Ready Mix mining site.

Estimated Completion Date:

Robertson's Ready Mix Circuit Re-route 6/30/2028
Project Description:
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CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$0
$3,500,000 $2,500,000 $1,000,000
$3,500,000 $2,500,000 $1,000,000 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $3,500,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $0
CIAC (Grant) $3,500,000
Funding Source Total
This project will accommodate roadway improvements to connect Sun Lakes Blvd from Highland Home Road to Sunset Ave.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
Planning and field investigation for this project started in 2021. BEU completed a design to convert overhead facilities to underground construction to accommodate the roadway extension. The project was bid to a construction contractor and approved by City Council in late 2025. Since BEU is obligated to continue fire mitigation efforts, improvements to the overhead infrastructure that will remain will include line hardening elements to protect from and prevent wildfire in the HFTD. BEU anticipates construction to begin toward the end of FY 26/27, and continue thru FY 27/28. Electric improvements for this project will be grant funded.

Budget Distribution Est. Amount
$125,000
$0
$0
$50,000
$3,325,000
$3,500,000
Project Title:

BEU will relocate transmission, distribution, and fiber optic infrastructure on Westward Ave/Sun Lakes Blvd due to roadway improvements. This project will include both underground conversion and overhead line hardening as these improvements will occur in the Tier 2 High Fire Threat District (HFTD).

Estimated Completion Date:

Sun Lakes Blvd Extension - Electric Relocation 12/30/2027 Project Description:
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.6 – Substation Capacity Analysis
The table below represents the substation capacity analysis based on the 2030 substation demand forecast. As shown in the table, the Midway, San Gorgonio, and Sunset summer forecast exceeds the base rating of their respective transformer; however, the forecast does not exceed the max rating of the transformer, therefore, no substation improvements are required in the 5- Year CIP.

The table also shows that the BEU system non-coincident peak exceeds the SCE Banning substation transformer base capacity for the summer and winter forecast and also the max capacity in the summer. Based on the non-coincident forecast, the total BEU system load is expected to exceed the max capacity by the summer of 2026. It is recommended that BEU continue to coordinate with SCE on the substation transformer capacity and develop a plan to increase the substation transformer capacity through the end of the forecast period.

Table 5.6-1 – Substation Capacity Analysis
2030 Transformer Transformer Transformer Transformer Transformer Transformer kW
Demand Base Max High Side Low Side % Capacity % Capacity Forecast MVA MVA kV kV Base Max
22nd Street
S 11,270 15 25 34.4 12.47 75% 45%
W 8,672 18 29 48% 30%
Ivy
S 6,598 15 25 69x34.4 12.47 44% 26%
W 5,604 18 29 31% 19%
Midway
S 17,197 2 x 7.5 2 x 9.375 34.4 12.47 115% 92%
W 11,040 18 22 61% 51%
San
Gorgonio
S 21,465 2 x 10 2 x 14 69x34.5 12.47 107% 77%
W 19,809 24 32 83% 62%
Stagecoach
S 7,397 10 12.5 69x34.5 12.47 74% 59%
W 4,196 12 14 35% 29%
Sunset
S 15,077 15 25 69x34.5 12.47 101% 60%
W 10,064 18 29 56% 35%
SCEBanning
S 63,576 2 x 21 2 x 28 34.5 151% 114%
W 53,737 50.4 64 107% 83%
Notes:

1. Individual substation kW Demand forecast shown as the non-coincident peak.

2. SCE-Banning kW Demand forecast shown as the coincident peak.

3. Base winter rating determined by IEEE C57.91-1995, Table 4 (1% increase per °C)

4. Max winter rating determined by IEEE C57.91-1995, Table 4 (0.75% increase per °C) 5-46
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.7 – Distribution System Analysis
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include 14 projects to switch load to adjacent lines to reduce single-phase line loading at a total estimated cost of $41,700, 2 projects for new line construction of 600’ totaling $336,400, 9 projects for singlephase to three-phase line rebuild of 10,107’ totaling $2,142,100, and 2 projects for three-phase line rebuild using larger conductor of 2,130’ totaling $285,500. The total estimated cost for distribution system improvements is $2,805,700.

The following pages detail the recommended distribution system improvements by substation and circuit.
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
22ND STREET SUBSTATION
CKT 63
CIP-1
Issue: UG146168, 1Ø, #2 URD line with 36 amps, 94 thru consumers.

Resolution: Close switch at vault 143589 at the intersection of Weather Way and Spring Pl. and open at the transformer at pad 146130 at the intersection of Summer Set Cir. and Amper Sky St. and feed load along Autumn Ln. from SW145671-B. Estimated cost: $2,300 (2030).

Image 5.7-1 – CIP Project 1
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-2
Issue: UG33x363, 1Ø, 1/0 URD line with 49 amps, 102 thru consumers.

Resolution: BEU will inspect the facilities at the intersection of Lake Buena Vista Way and Birdie Dr. and switch some of this B phase load along Lake Buena Vista Way west of Birdie Dr. to the 3Ø line that runs along Birdie Dr. Estimated cost: $2,000 (2028).

Image 5.7-2 – CIP Project 2
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-3
Issue: UG29v17, 1Ø, 1/0 URD with 97 amps, 239 thru consumers.

Resolution:
• Close switch at vault 101946 and open at vault 102621 at the intersection of Indian Canyon Dr. and Masters Dr. and backfeed all load north from SW103762-A. • Close switch at pad 103628 and open at pad 103513 to switch load south from pad 103628A.
• Install 3Ø vault at the intersection of Indian Canyon Dr. and Birdie Dr. and change feed of UG33x433 from 3Ø line along Birdie Dr. to feed all load along Indian Canyon Dr. west of Birdie Dr. from the 3Ø vault. Estimated cost: $5,900 (2026).

Image 5.7-3 – CIP Project 3
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-4
Issue: UG18v9, 1Ø, 1/0 URD with 96 amps, 230 thru customers.

Resolution:
• Change feed of line along Bradley St. to feed from 3Ø junction box and connect UG133185 by closing a switch at vault 103523 and open at the intersection of Sawgrass Dr. and Litchfield Ct. to serve all load north of vault 103523. • Backfeed UG109597 from 3Ø UG4550 and open around UG33x474 along Brackenridge Ave. Estimated cost: $4,000 (2027).

Image 5.7-4 – CIP Project 4
CKT 64
Issue: None

IVY SUBSTATION
CKT 11
Issue: None
CKT 12
Issue: None
CKT 13
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Issue: None

MIDWAY SUBSTATION
CKT 21
CIP-5
Issue: UG33x282, 1Ø, #2 URD with 65 amps, 97 thru consumers.

Resolution:
• Construct a new, 300’, 1Ø, 1/0 AL URD primary voltage tie from pad 42503 to pad 42498, crossing W. Pinehurst Dr. and following S. Shoal Creek St. • Open the line at pad 42491 and serve all load to the west from the 1Ø line at S. Shoal Creek St. and Riveria Ave. Estimated cost: $114,600 (2027).

Image 5.7-5 – CIP Project 5
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-6
Issue: UG33x149, 1Ø, 2 URD with 64 amps, 86 thru consumers.

Resolution: Replace 600’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from vault 36857 along Rivera Ave. just south of Bermuda Dunes Ave to vault 36879 at the intersection of W. Forest Oaks Ave and W. Glen Abbey Way and split the load between multiple phases. Estimated cost: $223,300 (2027).

Image 5.7-6 – CIP Project 6
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-7
Issue: UG117v, 1Ø, #2 URD with 41 amps, 65 thru consumers.

Resolution Construct a new, 600’, 1Ø, 1/0 URD primary voltage tie from vault 41797 to pad 41823. Open at pad 41830 and switch all load southeast of Nicklaus Dr. along Hogan Ave. to feed from pad 41797. Estimated cost: $221,800 (2028).

Image 5.7-7 – CIP Project 7
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-8
Issue: UG33x244, 1Ø, 1/0 URD with 58 amps, 84 thru consumers.

Resolution: Close switch at vault 40252 and open at pad 40237 along Woodland Dr. to split west of Woodland Dr. to feed from vault 40252. Estimated cost: $2,100 (2028).

Image 5.7-8 – CIP Project 8
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-9
Issue: UG33x232, 1Ø, 1/0 URD with 37 amps, 41 thru consumers.

Resolution: Close BØ at pad 40257 along Fairway Oaks Ave. and open Transformer303 at the intersection of Mission Hills Dr. and Cooper Creek Dr. and feed load along Mission Hills Dr. from pad 40257. Estimated cost: $2,100 (2030).

Image 5.7-9 – CIP Project 9
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-10
Issue: UG33x199, 1Ø, 1/0 URD with 100 amps, 98 thru consumers (A phase), UG33x195, 1Ø, 1/0 URD with 114 amps, 162 thru consumers (B phase), and UG33x184, 1Ø, 1/0 URD with 74 amps, 99 thru consumers (C phase).

Resolution:
• Close switch at vault 38245 and open at vault 38212 at the intersection of Spring Hills Cr.

And Sheehan Cir. and backfeed all load west of Sheehan Cir. from vault 38245. • Change the feed of UG33x189 to feed from another phase at the 3Ø vault 38191 at the intersection of Riveria Ave. and Sunningdale St.
• Change feed of UG33x190 to feed from another phase at the 3Ø vault 38240 along Birdie Dr.
• Change feed of UG33x212 to feed from another phase at the 3Ø vault 38191 at the intersection of Riveria Ave. and Sunningdale St.
• Change feed of UG33x211 to feed from the 3Ø pad 38237 at the intersection of Cog Hill Rd. and Breckenridge Ave. and open at pad 38248 and feed all load to the west along Breckenridge Ave. to feed from pad 38237. Estimated cost: $6,700 (2026).

Image 5.7-10 – CIP Project 10
CKT 22
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 23
CIP-11
Issue: UG33x71, 1Ø, 1/0 URD with 37 amps, 77 thru consumers.

Resolution:
• Replace 1,300’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from pullbox Pb32117 along W.

Wilson St. to vault 32103 at the intersection of Marian Way and Dawn Way. • Close switch at marker M32898 along Beverly Dr. and open at pad 35930 along Evelyn Dr. Estimated cost: $547,600 (2030).

Image 5.7-11 – CIP Project 11
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 24
CIP-12
Issue: UG33x101, 1Ø, 1/0 URD with 61 amps, 93 downline customers.

Resolution: Close switch at pad 34934 and openUG33x118 at pad 34956 the intersection of Twin Hills Dr. and Links Ave. and backfeed load along Big Springs Dr. to feed from 3Ø lie to north at switch pad 34934. Estimated cost: $2,100 (2027).

Image 5.7-12 – CIP Project 12
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

SAN GORGONIO SUBSTATION
CKT 51
CIP-13
Issue: OH189362, 1Ø, #4 CU line with 105 amps, 174 thru consumers.

Resolution: Rebuild 1,391’ of 1Ø, #4 Cu line to 3Ø, 1/0 ACSR along W. Nicolet St. from pole number 189371 to pole number 192590. Estimated cost: $172,200 (2026).

Image 5.7-13 – CIP Project 13
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-14
Issue: OH206564, 1Ø, #4 CU line with 68 amps, 106 thru consumers.

Resolution: Rebuild 1,183’ of 1Ø, #4 and #6 CU line to 3Ø, 1/0 ACSR along N. 12th St. from pole number 190013 to pole number 158883. Estimated cost: $148,700 (2027).

Image 5.7-14 – CIP Project 14
CKT 52
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 53
CIP-15
19 Issue: UG295266, 3Ø, 750 MC URD conductor reaches 63% capacity.

Resolution: Open after OH240725 and close switch at Pole23857 and reconfigure SG233747 to 4=CLOSED, 3=CLOSED, 2=CLOSED and 1=OPEN to switch load to the Ivy substation. Estimated cost: $2,000 (2026).

Image 5.7-15 – CIP Project 15
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 54
CIP-16
Issue: UG295263, 3Ø, 750 MCM feeder exit and 336 ACSR exceeds 60% capacity thru OH252561 (67% capacity is the highest).

Resolution:
• Disconnect line section OH2138 from OH2137 (line heading north on N. Alessandro St. north of E. Williams St.) and close switch at Pole284048 (along N. Alessandro St. between George St. and E. Wilson St.).
• Change the feed of line section OH194778 to feed from OH2138 (which will now be fed from Stagecoach CKT 8) and serve all the load along E. Williams St. west of N. Alesandro St. to feed from Stagecoach CKT8. Estimate cost: $3,400 (2029).

Image 5.7-16 – CIP Project 16
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

STAGECOACH SUBSTATION
CKT 7
CIP-17
Issue: OH259474, 1Ø, #6 Cu line with 41 amps, 80 thru consumers.

Resolution: Rebuild 871’ of 1Ø, #6 CU line to 3Ø, 1/0 ACSR along E. Theadore St. from pole number P6970COB to pole number P2891COB. Estimated cost: $119,800 (2029).

Image 5.7-17 – CIP Project 17
5-64
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-18
Issue: OH268700, 1Ø, #4 ACSR line with 46 amps, 105 thru consumers.

Resolution: Rebuild 1,790’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR along E. Nicolet St. from pole number P6956COB to pole number Pole194713. Estimated cost: $236,700 (2029).

Image 5.7-18 – CIP Project 18
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-19
Issue: OH255103, 1Ø, #4 ACSR line with 41 amps, 80 thru consumers.

Resolution: Rebuild 1,417’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR along E. Nicolet St. from pole number P6956COB to pole number FP255128. Estimated cost: $193,400 (2029).

Image 5.7-19 – CIP Project 19
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 8
CIP-20
Issue: OH280416, 1Ø, 1/0 ACSR line with 36 amps, 61 consumers.

Resolution: Rebuild 955’ of 1Ø, 1/0 ACSR and #2 ACSR line to 3Ø, 1/0 ACSR beginning on E.

Indian School Ln. then heading north to E. Repplier Rd. from pole number P1344COB to pole number 280435. Estimated cost: $134,300 (2030).

Image 5.7-20 – CIP Project 20
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

SUNSET SUBSTATION
CKT 72
CIP-21
Issue: UG278161 Feeder Exit, 3Ø, 750 MCM URD conductor reaches 70% capacity.

Resolution: It is recommended to serve the Crestwood Communities load addition from CKT 77 at UG3.
• Change the feed of UG6 for the load along Mocking Bird Ln. to CKT 77 at vault SV100086. • Change the feed of UG18 for the load along Hillside Dr. to CKT 77 at vault SV100180. • Change the feed of UG33 for the load along Evergreen Ln. to CKT 77 at vault SV100084. • Change the feed of UG82 for the load along Oak Ln. to CKT 77 at junction box Pb20340.

Estimated cost: $2,800 (2026).

Image 5.7-21 – CIP Project 21
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-22
Issue: UG59v, 1Ø, 1/0 URD with 56 amps, 177 thru consumers.

Resolution: Close switch at pad 23132 along Mc Govern Ave. and open at pad 253139 and switch all load south and east to serve from pad 23132 along Mc Govern Ave..

Estimated cost: $2,100 (2028).

Image 5.7-22 – CIP Project 22
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-23
Issue: UG5v1, 1Ø, 4/0 URD with 55 amps, 174 thru consumers.

Resolution: Close switch at pad 23137 along W. Wilson St. and open at PAD 23138 along Bunker Hill Rd. and serve all load along Catchen Rd. from pad 23137. Estimated cost: $2,100 (2028).

Image 5.7-23 – CIP Project 23
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-24
Issue: OH71, 3Ø, 4/0 ACSR conductor reaches 75% capacity and continued to be greater than 60% capacity thru OH143.

Resolution: Rebuild 1,693; of 3Ø, 4/0 ACSR line to 3Ø, 336 ACSR along W. Wilson St. from pole number 14759 to pole number 14817. Estimated cost: $219,300 (2026).

Image 5.7-24 – CIP Project 24
5-71
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-25
Issue: OH183168, OH183140, and OH183149, 3Ø, #4 ACSR conductor reaches 60% capacity.

Resolution: Rebuild 437’ of 3Ø, #4 CU line to 3Ø, 336 ACSR along N. 16th St. between W.

Nicolet St. and W. Wilson St. from pole number 183146 to pole number Pole183139. Estimated cost: $66,200 (2030).

Image 5.7-23 – CIP Project 25
CKT 74
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 76
CIP-26
Issue: UG43v, 1Ø, 1/0 URD with 39 amps, 95 thru consumers.

Resolution: Replace 650’ of 1Ø, 1/0 URD line with 3Ø, 1/0 URD line from vault 28573 along W. Wilson St. to vault 28595 at the intersection of W. Hoffer St. and Foothill Dr.

Estimated cost: $336,100 (2029).

Image 5.7-26 – CIP Project 26
CKT 77
Note: The feeder extends along Mountain Ave. along with CKT 72 but does not have any load connected. SEE CKT 72 recommendations.

BANNING SUBSTATION (34.5 kV Analysis)
CKT 1
Issue: None
CKT 2
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 3
CIP-27
Issue: The model shows CKT 3 feeding the Midway, Ivy, and Stagecoach substations.

OH248992 Feeder Exit, 3Ø, 336 ACSR reaches 95% capacity, OH2296, 3Ø, 4/0 ACSR reaches 78% capacity, and OH2316, 3Ø, 4/0 ACSR reaches 62% capacity.

Resolution: Close the tie around Pole241891 and open the line at Pole262449 to switch load from CKT 3 to CKT 1. This will change the feed of the Stagecoach substation to be served by CKT1. Estimated cost: $2,100 (2026).

Image 5.7-27 – CIP Project 27
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.8 – Total Cost Estimate
The table below contains a breakdown of the total estimated cost of the 5-Year CIP.

Table 5.8-1 – Total 5-Year CIP Cost Estimate
2026-2030 CIP
2026 2027 2028 2029 2030 Totals
OH Maintenance Program
Total Cost $604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 Capital-Maintenance Projects
Total Cost $5,460,000 $3,154,500 $1,690,000 $4,980,000 $5,500,000 $20,784,500 CIAC $4,918,750 $1,000,000 $0 $2,375,000 $1,000,000 $9,293,750 BEU Funding Cost $541,250 $2,154,500 $1,690,000 $2,605,000 $4,500,000 $11,490,750 System Improvements Projects
Total Cost $411,000 $492,700 $230,100 $919,400 $752,500 $2,805,700 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $411,000 $492,700 $230,100 $919,400 $752,500 $2,805,700 5-year CIP Cost
Total Cost $6,475,198 $4,269,524 $2,561,094 $6,978,672 $7,364,150 $27,648,638 CIAC $4,918,750 $1,000,000 $0 $2,375,000 $1,000,000 $9,293,750 BEU Funding Cost $1,156,448 $3,269,524 $2,561,094 $4,603,672 $6,364,150 $18,354,888 For the BEU funding cost, 22% is for OH Maintenance Program, 63% is for Capital Maintenance Projects, and 15% is for System-Improvement Projects.
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

6.0 – 15 – YEAR ESMP

6.1 – Overhead Maintenance Program
The Overhead Maintenance Program includes the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect 20 poles per week for the years 2031 thru 2035 and 25 poles per week for the years 2036 thru 2045. This totals to 1,040 poles inspected per year between 2031 and 2035 and 1,300 poles inspected between 2036 and 2045 for a grand total of 18,200 poles inspected for the duration of the 15-Year ESMP. An estimated cost of $322 per pole inspection was used for 2031 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole inspections for the 15-Year ESMP is $7,350,010.

It is projected that BEU will replace 100 poles per year for the years 2031 thru 2045. This totals to 1,500 poles replaced for the duration of the 15-Year ESMP. An estimated cost of $8,935 per pole replacement was used for 2031 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole replacements for the 15-Year ESMP is $16,618,732.

The total estimated cost for the Overhead Maintenance Program for the 15-year ESMP is $23,968,742. The table below shows a breakdown of the Overhead Maintenance Program.

Table 6.1-1 – Overhead Maintenance Program Costs 2031 thru 2035 2031 2032 2033 2034 2035 Total
Number of
Poles
Inspected
1,040 1,040 1,040 1,040 1,040 5,200
Cost per
Inspection �‬‮‮ �‬‬‮ �‬‮ �‬‮ �‬‬ -
Total Cost of
Inspection $335,290 $345,349 $355,709 $366,380 $377,372 $1,780,100 Number of
Poles
Replaced
100 100 100 100 100 500
Cost per
Replacement $8,935 $9,203 $9,479 $9,764 $10,057 -
Total Cost of
Replacement $893,532 $920,338 $947,949 $976,387 $1,005,679 $4,743,885 6-1
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 6.1-2 – Overhead Maintenance Program Costs 2036 thru 2040 2036 2037 2038 2039 2040 Total
Number of Poles
Inspected 1,300 1,300 1,300 1,300 1,300 6,500
Cost per Inspection $374 $385 $397 $408 $421 -
Total Cost of
Inspection $485,866 $500,442 $515,455 $530,919 $546,847 $2,579,529 Number of Poles
Replaced 100 100 100 100 100 500
Cost per
Replacement $10,358 $10,669 $10,989 $11,319 $11,659 -
Total Cost of
Replacement $1,035,849 $1,066,924 $1,098,932 $1,131,900 $1,165,857 $5,499,463 Table 6.1-3 – Overhead Maintenance Program Costs 2041 thru 2045 2041 2042 2043 2044 2045 Total
Number of Poles
Inspected 1,300 1,300 1,300 1,300 1,300 6,500
Cost per Inspection $433 $446 $460 $473 $488 -
Total Cost of
Inspection $563,252 $580,150 $597,554 $615,481 $633,945 $2,990,381 Number of Poles
Replaced 100 100 100 100 100 500
Cost per
Replacement $12,008 $12,369 $12,740 $13,122 $13,515 -
Total Cost of
Replacement $1,200,833 $1,236,858 $1,273,964 $1,312,182 $1,351,547 $6,375,384 6-2
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ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

6.2 – CAPITAL MAINTENANCE PROJECTS
BEU has identified 6 Capital Maintenance Projects to include in the 15-year ESMP. The total estimated cost for these projects is $8,350,000. It is projected that BEU will receive $3,000,000 in contributions in aid to these projects bringing the total BEU funding cost to $5,350,000.

The following tables list the Capital Maintenance projects that have been identified for inclusion to the 15-year ESMP.

Table 6.2-1 – Capital Maintenance Project Costs
Project Description Year Total Cost CIAC
BEU
Funding
Cost
Midway Substation Upgrades (breaker
replacement and SCADA-ready
upgrades and future full replacement)
2031 $1,000,000 $0 $1,000,000

34.5/12.47/fiber Relocation on 4th St
from Westward Ave to Lincoln St 2031 $1,500,000 $1,500,0001 $0 Underground Conversion from
Apex/Ramsey to Joshua Palmer 2031 $850,000 $0 $850,000
Underground Conversion at Wilson St
from Smith Creek to Highland Home Rd 2031 $500,000 $0 $500,000

34.5/12.47/fiber I-10 Crossing at
Hathaway from John St to Ramsey St 2031 $1,500,000 $1,500,0002 $0 Overhead Transmission System
Extension (Hoffer/Hathaway to
Stagecoach Substation)
2031-
2032 $3,000,000 $0 $3,000,000
Total 15-Year ESMP Capital Maintenance Cost $8,350,000 $3,000,000 $5,300,000 1 Up to 100% funding from Rancho San Gorgonio Development 2 Up to 100% funding from Hillwood Development
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15-YEAR ESMP

6.3 – SUBSTATION CAPACITY ANALYSIS
The table below represents the substation capacity analysis based on the 2045 substation demand after distribution system improvements including adding the new Smith Creek Substation, new feeders out of Stagecoach and Sunset, and load switching recommendations.

As shown in the table, the San Gorgonio, Stagecoach, and Sunset substations summer projected peak exceeds the base rating of their respective transformer; however, with the exception of the Stagecoach Substation, the load does not exceed the max rating of the transformer. For the Stagecoach Substation, it is recommended to replace the existing base 10 MVA transformer with a base 15 MVA transformer before the summer 2040 peak. With this improvement, the projected load will not exceed the base rating or the max rating of the new transformer thru the end of this ESMP.

The table also shows that the BEU system non-coincident peak exceeds the SCE Banning substation transformer base capacity for the summer and winter forecast and also the max capacity in the summer. Based on the non-coincident forecast, the total BEU system load is expected to exceed the max capacity by the summer of 2026. It is recommended that BEU continue to coordinate with SCE on the substation transformer capacity and develop a plan to increase the substation transformer capacity through the end of the ESMP period.

Table 6.3-1 – Substation Capacity Analysis
2045 kW
Demand
Transformer
Base
Transformer
Max
Transformer
High Side
Transformer
Low Side
Transformer
% Capacity
Transformer
% Capacity
Forecast MVA MVA kV kV Base Max
22nd Street
S 6,250 15 25 34.4 12.47 42% 25%
W 4,809 18 29 27% 17%
Ivy
S 11,446 15 25 69x34.4 12.47 76% 46%
W 9,679 18 29 54% 34%
Midway
S 0 2 x 7.5 2 x 9.375 34.4 12.47 0% 0%
W 0 18 22 0% 0%
Smith Creek
S 32,566 2 x 20 2 x 37.5 69x34.4 12.47 81% 43%
W 20,906 48 75 44% 28%
San
Gorgonio
S 19,996 2 x 10 2 x 14 69x34.5 12.47 100% 71%
W 18,391 24 32 77% 57%
Stagecoach
S 14,764 10 12.5 69x34.5 12.47 148% 118%
W 8,374 12 14 70% 58%
Sunset
S 20,920 15 25 69x34.5 12.47 139% 84%
W 13,441 18 29 75% 47%
SCEBanning
S 90,738 2 x 21 2 x 28 34.5 216% 162%
W 75,580 50.4 64 150% 117%
Notes:

1. Individual substation kW Demand forecast shown as the non-coincident peak.

2. SCE-Banning kW Demand forecast shown as the coincident peak.

3. Base winter rating determined by IEEE C57.91-1995, Table 4 (1% increase per °C)

4. Max winter rating determined by IEEE C57.91-1995, Table 4 (0.75% increase per °C) 6-4
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15-YEAR ESMP

6.4 – DISTRIBUTION SYSTEM ANALYSIS
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing for the 15-year ESMP. The analysis results include 5 projects to switch load to adjacent lines at a total estimated cost of $17,100, 2 projects for new overhead line construction totaling $1,219,000, 9 projects for rebuilding overhead lines totaling $1,926,600, 10 projects for new underground line construction totaling $7,107,100 and 4 projects for replacing underground line with larger conductor totaling $1,269,500. The total estimated cost for distribution system improvements for the 15-year ESMP is $11,539,300.

The following pages detail the recommended distribution system improvements by substation and circuit.
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15-YEAR ESMP
22ND STREET SUBSTATION
CKT 63
ESMP-1
Issue: UG33x303, 1Ø, #2 URD line with 41 amps, 41 thru consumers.

Resolution:
• Replace 580’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from vault 44888 to pad 44888 along Indian Wells Rd.
• Split the load between multiple phases.
• Estimated cost: $345,600 (2041).

Image 6.4-1 – ESMP Project 1
6-6
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
ESMP-2
Issue: UG9v7, 1Ø, 1/0 URD line with 41 amps, 86 thru consumers.

Resolution:
• Construct 540’ of 1Ø, 1/0 URD line from pad 46153 to pad 108770 along Pauma Valley Rd. utilizing pull boxes Pb101706, Pb108810, PB108831, and Pb108819 • Open after line section UG9v9 at vault 108834
• Change the feed of line section UG33x490 along Eagle Trace Ln. at vault 108834 to feed from the north.
• Change the feed of UG33x489 along Warwick Hills Way at pad 108770 to feed from the north.
• Estimated cost: $388,100 (2045).

Image 6.4-2 – ESMP Project 2
CKT 64
Issue: None

IVY SUBSTATION
CKT 11
Issue: None
6-7
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15-YEAR ESMP
CKT 12
ESMP-3
Issue: OH239297, 3Ø, #2 ACSR OH conductor reaches 73% capacity.

Resolution: Rebuild 423’ of 3Ø, 1/0 ACSR and #2 ACSR line to 3Ø, 336 ACSR along E.

Westward Ave and crossing E. Woodward Ave from Pole239250 to Pole239296.

Estimated cost: $120,400 (2044).

Image 6.4-3 – ESMP Project 3
CKT 13
Issue: None

MIDWAY SUBSTATION
The new Smith Creek Substation is planned for construction beginning in 2030 with a planned energization in 2031. All of the load currently served by the Midway Substation will be switched to Smith Creek. See the Smith Creek Substation writeup for system improvements required to support the load.
6-8
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15-YEAR ESMP

SAN GORGONIO SUBSTATION
CKT 51
ESMP-4
Issue: UG295264, 3Ø, 750 MCM conductor at the feeder exit reaches 66% capacity and OH1359, 3Ø, 336 ACSR conductor along W Lincoln St. reaches 62% capacity.

Resolution: Open SW209315-A at FP197794 Along George St. between N. 3rd St. and N 2nd St. and switch a portion of load to the Stagecoach substation. Note: In order for this to be completed without further problems, CKT’s 5 and 6 out of the Stagecoach substation will be constructed. See the Stagecoach system improvement recommendations for projects required to complete this load switch. Estimated cost: $3,100 (2041).

Image 6.4-4 – ESMP Project 4
ESMP-5
Issue: OH189322, 1Ø, #6 CU line with 59 amps, 57 thru consumers.

Resolution: Rebuild 625’ of 1Ø, #6 and #4 CU line to 3Ø, 1/0 ACSR from Pole189367 to Pole198056 between W. Nicolet St. and W. Williams St. and just west of N. 6th St.

Once the line is rebuilt to three-phase, balance the taps between the three phases.

Estimated cost: $132,800 (2040).
6-9
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15-YEAR ESMP
Image 6.4-5 – ESMP Project 5
CKT 52
Issue: None
CKT 53
ESMP-6
Issue: UG241798, 1Ø, 2 URD with 59 amps, 46 thru consumers.

Resolution: Open the single-phase line at Vault 146193 and backfeed the line at Pad 146238 to split up the single-phase line and serve from another source. Estimated cost:
$2,900 (2039).
6-10
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15-YEAR ESMP
Image 6.4-6 – ESMP Project 6
ESMP-7
Issue: OH237438, 1Ø, #4 ACSR line with 57 amps, 34 thru consumers.

Resolution: Rebuild 3,155’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR from FP237936 to Pole237034 beginning at the intersection of S. Hargrave St. and Wesley St. and ending at the intersection of S. Hathaway St. and Porter St. Once the line is rebuilt to three-phase, balance the taps between the three phases. Estimated cost:
$539,700 (2038).
6-11
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15-YEAR ESMP
Image 6.4-7 – ESMP Project 7
CKT 54
Issue: None

STAGECOACH SUBSTATION
CKT 5 & 6
In order to balance the load at the Stagecoach substation and also to switch load from the San Gorgonio and Sunset substations to reduce conductor loading, it is recommended to build out CKT’s 5 and 6 out of the Stagecoach substation. The projects listed below are recommended to construct CKT’s 5 and 6 along with switching load from Stagecoach CKT’s 7 and 8, San Gorgonio CKT 51, and Sunset CKT 72. The two need circuits will head south from the substation to E.

Theodore St., head west on E. Theodore St. to N. Alessandro St., head south on N. Alessandro St. to E. Hoffer St. and then head west on E. Hoffer St. and end just west of N. San Gorgonio Ave.

Circuit 5 will be express to this point.

ESMP-8
• Construct 2, 150’; 3Ø, 750 MCM feeder exits from Bay 5 and Bay 6 to pole P4301COB.

Estimated cost: $165,800 (2035).
6-12
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-8 – ESMP Project 8
ESMP-9
• Rebuild 200’ of 1Ø, #2 ACSR line to double circuit 3Ø, 477 ACSR from pole P4301COB to pole P4302COB along the substation back entrance road. • Create open point at pole P2999COB along E. Theodore St. and switch a portion of load from CKT 7 to the new CKT 6.
• Estimated cost: $57,500 (2035).
6-13
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-9 – ESMP Project 9
ESMP-10
• Rebuild 650’ of 3Ø, 1/0 ACSR line to double circuit 3Ø, 477 ACSR from pole P4302COB to pole GT68215 along E. Theodore St. from N. Hermosa Ave heading west to just past Vista Serna Ave. Estimated cost: $157,400 (2035).
6-14
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-10 – ESMP Project 10
ESMP-11
• Rebuild 900’ of 1Ø, #2 CU line to double circuit 3Ø, 477 ACSR from pole GT68215 to pole P2330COB along E. Theadore St. east of N. Alessandro St. Estimated cost: $181,800 (2035).
6-15
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-11 – ESMP Project 11
ESMP-12
• Construct 100’ of double circuit 3Ø, 477 ACSR line from pole P2330COB to pole P2331COB along E. Theadore St. east of N. Alessandro St. • Create open point at Pole282646 along N. Alessandro St. just north of E. Theodore St. and switch a portion of load from CKT 8 to CKT 6.
• Estimated cost: $31,800 (2035).
6-16
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-12 – ESMP Project 12
ESMP-13
• Rebuild 2,150’ of 3Ø, 336 ACSR line to double circuit 3Ø, 336 ACSR from pole P2331COB to Pole283017 heading south along N. Alessandro St and then west along W. Hoffer St. • At Pole283017, switch the tap heading north towards W. Gillman St. to CKT 5 and switch the tap heading south towards E. Wilson St. to CKT 6.
• Estimated cost: $455,400 (2035).
6-17
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-13 – ESMP Project 13
CKT 7
Issue: None
CKT 8
ESMP-14
Issue: OH282953, 1Ø, #4 CU line with 37 amps, 52 consumers.

Resolution: Rebuild 510’ of 1Ø, #4 CU line to 3Ø, 1/0 ACSR along E. Theodore St. west of N.

Alessandro St from pole P2331COB to pole 30733CWT. Estimated cost: $115,200 (2043).
6-18
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-14 – ESMP Project 14

SUNSET SUBSTATION
CKT 72
ESMP-15
Issue: UG278161 Feeder Exit, 3Ø, 750 MCM URD conductor reaches 95% capacity and is greater than 80% capacity thru UG20. OH71 3Ø, 336 ACSR reaches 76% capacity and is greater than 60% capacity thru OH165. OH162 3Ø, 4/0 ACSR reaches 80% capacity and is greater than 60% capacity thru OH156.

Resolution: It is recommended to open at Pole175357 at the intersection of N. 22nd St. and W.

Nicolet St. and close at Pole200537 along W. Gilman St. just west of N. 8th St. and switch load to the new Stagecoach CKT 5. Estimated cost: $2,800 (2036). 6-19
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-15 – ESMP Project 15
ESMP-16
Issue: With the load switch from Stagecoach CKT 72 to Stagecoach CKT 5 as described in ESMP-15, the 3Ø, #2 ACSR line at OH200538 reaches 101% Resolution: Rebuild 875’ of 3Ø, #2 ACSR line to 3Ø, 477 ACSR from Pole200537 to Pole213210 along W. Gilman St. between N. 8th St and 11th St. Estimated cost:
$166,400 (2037).
6-20
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-16 – ESMP Project 16
ESMP-17
Issue: OH213258, 1Ø, #2 ACSR line with 41 amps, 73 consumers Resolution: It is recommended to open at Pad 28196 and close at Pad 28229 and split the load between W. Gilman St. and W Hoffer St. west of N. 8th St. from two different threephase lines. Estimated cost: $3,400 (2042). 6-21
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-17 – ESMP Project 17
CKT 74
Issue: None
6-22
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
CKT 76
ESMP-18
Issue: Underground feeder exit, 3Ø, 750 MCM reaches 110% capacity and is greater than 60% capacity through UG2vQ6 at Vault 31064.

Resolution:
• Utilize CKT 78 and create a new feeder to serve the south west side of the Atwell Subdivision. See Image 6.4-20 below for the feeder plan recommendation. • Using the existing empty conduit that is in the same trench as CKT 76:
o Install 1,862’ of 3Ø, 750 MCM from the feeder bay exit to Vault LV100172 at the intersection of Highland Home Rd. and Mountain Ave. using the existing conduit. o Install 2,706‘ of 3Ø, 750 MCM from Vault LV100172 to Vault SP100103 along Highland Home Rd. north of Meadowline Way using the existing conduit and connect to cabinet #2 in switchgear SW12-2116 while removing the connection between Vault SP100102 cabinet #1 and Vault SP100103 cabinet #2. This will switch all load along Meadowline Way west of Highland Home Rd. to CKT 78. o Install 1,400’ of 3Ø, 750 MCM from Vault SP100109 cabinet 1 to Switchgear SG290766 following Meadowline Way.
o Open at Vault M98523 along N. Highland Springs Ave. and close SG290766 cabinet #2 along Meadowline Way and switch all load currently served from CKT 76 to the new CKT 78.
o Estimated cost: $927,000 (2031).

Image 6.4-18 – ESMP Project 18
6-23
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
EMSP-19
Issue: Despite the load switch to the new CKT 78, the underground feeder exit, 3Ø, 750 MCM is still over 60% capacity through Vault SP100105
Resolution:
• Utilize CKT 75 and create a new feeder to serve the south side of the Atwell Subdivision.

See Image 6.4-20 below for the feeder plan recommendation. • Using the existing empty conduit that is in the same trench as CKT 76:
o Install 1,862’ of 3Ø, 750 MCM from the feeder bay exit to Vault LV100172 at the intersection of Highland Home Rd. and Mountain Ave. using the existing conduit. o Install 2,706‘ of 3Ø, 750 MCM from Vault LV100172 to Vault SP100103 along Highland Home Rd. north of Meadowline Way using the existing conduit. o Install 2,953’ of 3Ø, 750 MCM from Vault SP100103 to Vault 30985 along W.

Wilson St. west of Highland Home Rd.
o At Vault 30985, switch the conductor heading west along W. Wilson St. to feed from the new CKT 75.
o Estimated cost: $1,032,400 (2032).

Image 6.4-19 – ESMP Project 19
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15-YEAR ESMP
Image 6.4-20 – FEEDER PLAN FOR CKT’S 75, 76, AND 78
CKT 77
Issue: None

NEW SMITH CREEK SUBSTATION
The new Smith Creek substation is planned to be constructed at a property owned by the City of Banning on the south side of Interstate 10 and will replace the Midway substation on the north side of Interstate 10. Construction for the new Smith Creek substation will begin in 2030 with an energization date in 2031. All four feeders currently served by Midway will be switched to Smith Creek. Additionally, four new feeders will be added at Smith Creek to served planned load additions between Interstate 10 and Westward Ave. The projects below are recommended to construct the new feeders out of Smith Creek to serve the existing Midway feeders and support existing and future load additions. Refer to Image 6.4-32 for the Smith Creek feeder plan.

Smith Creek CKT 21
Circuit 21 will be constructed to serve the existing Midway CKT 21. 6-25
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
ESMP-20
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104936. • Create open point at Pole104876 and serve the load on the south side of Interstate 10. • Create an open point at Pole104926 along Highland Home Rd. between CKT 21 and 25 • Create an open point at pole P6554COB along Westward Ave. between CKT 21 and 25 • Create an open point at Vault 40257 along Fairway Oks Ave. just north of Mission Hills Dr. between CKT 21 and 25
• Tie the three-phase line together at Vault 38231 at the intersection of Birdie Dr. and Cog Hill Rd.
• Estimated cost: $144,400 (2031).

Image 6.4-21 – ESMP Project 20
Smith Creek CKT 22
Circuit 22 will be constructed to serve the existing Midway CKT 22 and CKT 23.

ESMP-21
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104876 and use the existing Midway CKT 21 Interstate 10 crossing to serve the existing Midway CKT 22.

Estimated cost: $139,600 (2031).
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-22 – ESMP Project 21
Smith Creek CKT 23
Circuit 23 will be constructed to serve the existing Midway CKT 23.

ESMP-22
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104936 • Chage the feed at Pole104936 from Midway CKT 23 to Smith Creek CKT 23 • Use the existing Midway CKT 24 Interstate 10 crossing as the new Smith Creek CKT 23 highway crossing.
• Tie Midway CKT 23 to Smith Creek CKT 23 inside the current Midway substation to switch all of Midway CKT 23 to Smith Creek CKT 23
• Estimated cost: $144,400 (2031).
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-23 – ESMP Project 22
ESMP-23
Issue: The 750 MCM conductor at the feeder exit will reach 79% capacity, the 336 ACSR and 477 ACSR line up to and crossing Interstate 10 will reach 80% capacity and 64% capacity respectively, and the 750 MCM conductor at the current Midway CKT 23 feeder exit and heading along W. Ramsey St. to Lori Way exceeds 60% capacity.

Resolution:
• Construct 800’ of 3Ø, 750 MCM URD line from Vault 320963 to Vault 34038 and up to riser Pole34020 along W. Ramsey St between Highland Home Rd. and Lori Way. • Rebuild 2,165’ of single circuit 3Ø, 336 ACSR to double circuit 3Ø, 336 ACSR from Pole34020 to Pole206642 along W. Ramsey St. between Lori Way and Memorial Dr. • Rebuild 175’ of single circuit 3Ø, 750 MCM URD line to double circuit 3Ø, 750 MCM from riser Pole206642 to Vault 204676 along W. Ramsey St. at Memorial Dr. • At Vault 204676, leave the tap heading west along W. Ramey St. connected to CKT 23 and change the feed of the tap heading north along Memorial Dr. to CKT 22 using the newly constructed line.
• In SG266801 at the intersection of W. Ramsey St. and N. Highland Springs Ave., open cabinet #3
• Connect the three-phase between Vault 204734 and Vault 204656 to change the feed to Smith Creek CKT 22.
• Estimated cost: $1,187,200 (2036).
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CITY OF BANNING ELECTRIC UTILITY
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15-YEAR ESMP
Image 6.4-24 – ESMP Project 23
Smith Creek CKT 24
Circuit 24 will be constructed to serve the existing Midway CKT 24.

ESMP-24
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104900 and switch Midway CKT 24 to Smith Creek CKT 24. Estimated cost: $139,600 (2031). 6-29
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15-YEAR ESMP
Image 6.4-25 – ESMP Project 24
ESMP-25
Issue: UG1v, 3Ø, 1/0 URD line reaches 81% Capacity
Resolution: Replace 440’ of 3Ø, 1/0 URD with 3Ø, 750 MCM from Junction Box 34967 to Vault 34921 at the intersection of Northwood Ave. and Brooklawn Dr. Estimated cost:
$237,600 (2034).
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-26 – ESMP Project 25
Smith Creek CKT 25
Circuit 25 will be constructed to serve a portion of the existing Midway CKT 21.

ESMP-26
• Construct 2,745’ of double circuit 3Ø, 750 MCM URD line from the feeder bay to pole P6554COB at the intersection of Westward Ave. and S. Highland Home Rd. *Note, this will also be the route for Smith Creek CKT 26.
• At pole P6554COB, change feed from Midway CKT 21 to Smith Creek CKT 25. • Estimated cost: $1,652,900 (2031).
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-27 – ESMP Project 26
ESMP-27
Issue: UG1v24, 3Ø, 350 MCM URD conductor reaches 79% capacity.

Resolution: Replace 2,100’ of 3Ø, 350 AL MCM URD conductor with 3Ø, 750 MCM URD conductor from Vault 36923 located at the intersection of Sun Lakes Blvd. and Country Club Dr. and following Country Club Dr. to Vault 41797 at the intersection of Country Club Dr. and Hogan Ave. Estimated cost: $316,000 (2031). 6-32
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-28 – ESMP Project 27
Smith Creek CKT 26
Circuit 26 will be constructed to serve a portion of the existing Midway CKT 21 and 22nd Street CKT 63. See ESMP-26 for project to construct the circuit from Smith Creek.

ESMP-28
• Create open point at Pole104842 along Westward Ave to switch a portion of load from 22nd Street CKT 63
• At SG49762 along Country Club Dr. between Birdie Dr. and Gleneagles Dr., open cabinet #2 and change feed to Smith Creek CKT 25 at Vault 41797 along County Club Dr. at Hogan Ave.
• Estimated cost: $4,900 (2031).
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-29 – ESMP Project 28
ESMP-29
Issue: UG16v2, 3Ø, 350 MCM URD conductor reaches 70% capacity.

Resolution: Replace 2,420’ of 3Ø, 350 MCM URD with 3Ø, 750 MCM URD beginning at Pad 44570 along Sun Lakes Blvd, heading south on Country Club Dr. and ending at Vault 46131. Estimated cost: $370,300 (2033).
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-30 – ESMP Project 29
Smith Creek CKT’s 27 & 28
Circuits 27 and 28 will be constructed to serve new planned load in an area bordered by Interstate 10 and Westward Ave. on the north and south and Highland Home Rd. and Sunset Ave. on the east and west.

ESMP-30
• Construct 2, 3Ø, 750 MCM URD lines from the feeder bay heading due south from the substation to what will be the extension of W Lincoln St. and then heading east along W.

Lincoln St. to Sunset Ave at Pole104911. Estimated cost: $2,372,900 (2032). 6-35
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15-YEAR ESMP
Image 6.4-31 – ESMP Project 30
Image 6.4-32 – Smith Creek Feeder Plan
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15-YEAR ESMP

6.5 – TOTAL COST ESTIMATE
The tables below contain a breakdown of the total estimated cost of the 15-Year ESMP.

Table 6.5-1 – 15-Year ESMP Cost Estimate (2031-2035)
2031 2032 2033 2034 2035
OH Maintenance Program
Total Cost $1,228,822 $1,265,687 $1,303,658 $1,342,767 $1,383,050 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $1,228,822 $1,265,687 $1,303,658 $1,342,767 $1,383,050 Capital-Maintenance Projects
Total Cost $6,850,000 $1,500,000 $0 $0 $0
CIAC $3,000,000 $0 $0 $0 $0
BEU Funding Cost $3,850,000 $1,500,000 $0 $0 $0
System Improvement Projects
Total Cost $3,468,800 $3,405,300 $370,300 $237,600 $1,049,700 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $3,468,800 $3,405,300 $370,300 $237,600 $1,049,700 15-year ESMP Cost
Total Cost $11,547,622 $6,170,987 $1,673,958 $1,580,367 $2,432,750 CIAC $3,000,000 $0 $0 $0 $0
BEU Funding Cost $8,547,622 $6,170,987 $1,673,958 $1,580,367 $2,432,750 6-37
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Table 6.5-2 – 15-Year ESMP Cost Estimate (2036-2040)
2036 2037 2038 2039 2040
OH Maintenance Program
Total Cost $1,521,715 $1,567,367 $1,614,387 $1,662,819 $1,712,704 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $1,521,715 $1,567,367 $1,614,387 $1,662,819 $1,712,704 Capital-Maintenance Projects
Total Cost $0 $0 $0 $0 $0
CIAC $0 $0 $0 $0 $0
BEU Funding Cost $0 $0 $0 $0 $0
System Improvement Projects
Total Cost $1,190,000 $166,400 $539,700 $2,900 $132,800 CIAC $0 $0 $0 $0 $0
BEU Funding
Cost $1,190,000 $166,400 $539,700 $2,900 $132,800
15-year ESMP Cost
Total Cost $2,711,715 $1,733,767 $2,154,087 $1,665,719 $1,845,504 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $2,711,715 $1,733,767 $2,154,087 $1,665,719 $1,845,504 6-38
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Table 6.5-3 – 15-Year ESMP Cost Estimate (2041-2045)
2041 2042 2043 2044 2045 Totals
OH Maintenance Program
Total Cost $1,764,085 $1,817,007 $1,871,518 $1,927,663 $1,985,493 $23,968,742 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $1,764,085 $1,817,007 $1,871,518 $1,927,663 $1,985,493 $23,968,742 Capital-Maintenance Projects
Total Cost $0 $0 $0 $0 $0 $8,350,000
CIAC $0 $0 $0 $0 $0 $3,000,000
BEU Funding Cost $0 $0 $0 $0 $0 $5,350,000
System Improvement Projects
Total Cost $348,700 $3,400 $115,200 $120,400 $388,100 $11,539,300 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $348,700 $3,400 $115,200 $120,400 $388,100 $11,539,300 15-year ESMP Cost
Total Cost $2,112,785 $1,820,407 $1,986,718 $2,048,063 $2,373,593 $43,858,042 CIAC $0 $0 $0 $0 $0 $3,000,000
BEU Funding Cost $2,112,785 $1,820,407 $1,986,718 $2,048,063 $2,373,593 $40,858,042 For the BEU funding cost, 22% is for OH Maintenance Program, 63% is for Capital Maintenance Projects, and 15% is for System-Improvement Projects.
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7.0 – 2026-2045 ESMP SUMMARY

7.1 – Total Overhead Maintenance Program
The Overhead Maintenance Program includes the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect a total of 22,100 poles for the duration of the ESMP. An estimated cost of $278 per pole inspection was used for 2026 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole inspections for the ESMP is $8,501,657.

It is projected that BEU will replace 1,850 for the duration of the ESMP. An estimated cost of $7,746 per pole replacement was used for 2026 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole replacements for the ESMP is $19,525,523.

The total estimated cost for the Overhead Maintenance Program for the ESMP is $28,027,180.

7.2 – Total Capital Maintenance Program
BEU has identified 23 Capital Maintenance Projects to include in the ESMP. The total estimated cost for these projects is $29,134,500. It is projected that BEU will receive $12,293,750 in contributions in aid to these projects bringing the total BEU funding cost to $16,840,750.

7.3 – Total Distribution System Improvement Projects
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include:
• 19 projects to switch load to adjacent lines at a total estimated cost $58,800 • 12 projects for new underground line construction totaling $7,443,500 • 2 projects for new overhead line construction totaling $1,219,000, • 9 projects for single-phase to three-phase line rebuild totaling $2,142,100 • 11 projects for overhead line rebuild using larger conductor totaling $2,212,100 • 4 projects for replacing underground line using larger conductor totaling $1,269,500 The total estimated cost for distribution system improvements is $14,345,000. 7-1
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7.4 – Total 2026-2045 ESMP Cost Estimate
The table below contains a breakdown of the total estimate cost for the 2026-2045 ESMP. 2026-2045 Electric Service Master Plan
5-year CIP 15- Year ESMP Totals
OH Maintenance Program
Total Cost $4,058,438 $23,968,742 $28,027,180
CIAC $0 $0 $0
BEU Funding Cost $4,058,438 $23,968,742 $28,027,180
Capital Maintenance. Projects
Total Cost $20,784,500 $8,350,000 $29,134,500
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $11,490,750 $5,350,000 $16,840,750
System Improvement Projects
Total Cost $2,805,700 $11,539,300 $14,345,000
CIAC $0 $0 $0
BEU Funding Cost $2,805,700 $11,539,300 $14,345,000
Total ESMP Cost
Total Cost $27,648,638 $43,858,042 $71,506,680
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $18,354,888 $40,858,042 $59,212,930
7-2
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CITY OF BANNING, CALIFORNIA
2026-2045 ELECTRIC SERVICE MASTER PLAN
APRIL 2026
Prepared by:

Finley Engineering Company, Inc.

On behalf of:

Banning Electric Utility
Contact Information:

Finley Engineering Company, Inc.

PO Box 148, 104 E. 11th Street
Lamar, MO 64795
(417) 682-5531
www.finleyusa.com
City of Banning
99 E. Ramsey Street
Banning, CA 92220
951.922.3100
www.banningca.gov
16016

ENGINEERS CERTIFICATION
I, Christopher Adam Smart, P.E., herby certify that this 2026-2045 Electric Service Master Plan was prepared by me or under my direct Supervision and that I am a duly Licensed Professional Engineer under the laws of the state of California, license number E 25395.

X
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TABLE OF CONTENTS
Contents Page

1.0 - EXECUTIVE SUMMARY 1-1

1.1 - Introduction 1-1

1.2 – Purpose of Study 1-1

1.3 - Existing System Review 1-1

1.3. - Total ESMP Cost Estimate 1-2

2.0 - SYSTEM PLANNING CRITERIA 2-1

2.1 – Distribution System Planning Criteria 2-1

2.1.1 – Distribution System Design Criteria 2-1

2.2 – Substation Planning Criteria 2-2

2.3 – Basis of Cost Estimates 2-2

3.0 - LOAD FORECAST 3-1

4.0 - LAND USE PROJECTION 4-1

5.0 - 5-YEAR CAPITAL IMPROVEMENT PLAN (CIP) 5-1

5.1 - Executive Summary 5-5

5.1.1 - Introduction 5-5

5.1.2 - Purpose of Study 5-5

5.1.3 - General Conclusions and Recommendations 5-5

5.2 - Planning Criteria 5-7

5.2.1 - Distribution System 5-7

5.2.2 - Substation 5-8

5.2.3 - Basis of Cost Estimates 5-8

5.3 - System Forecast 5-11

5.4 - Overhead Maintenance Program 5-26

5.5 - Capital Maintenance Project 5-27

5.6 - Substation Capacity Analysis 5-46

5.7 - Distribution System Analysis 5-47

5.8 - Total 5-Year CIP Cost Estimate 5-75

6.0 - 15-Year ESMP 6-1

6.1 - Overhead Maintenance Program 6-1

6.2 - Capital Maintenance Projects 6-3

6.3 - Substation Capacity Analysis 6-4

6.4 - Distribution System Analysis 6-5

6.5 - Total 15-Year ESMP Cost Estimate 6-37

7.0 - Electric Service Master Plan (ESMP) Summary 7-1

7.1 - Total Overhead Maintenance Program 7-1

7.2 - Total Capital Maintenance Projects 7-1

7.3 - Total Distribution System Improvement Projects 7-1

7.4 - Total ESMP Cost Estimate 7-2
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TABLE OF CONTENTS
List of Table, Charts, and Images Page
Table 1.4-1 – Total ESMP Cost Estimate 1-2
Table 2.3-1 – Conductor Material Cost 2-2
Table 2.3-2 – Pole Material Cost 2-2
Table 2.3-3 – Transformer Material Cost 2-3
Table 2.3-4 – Framing Units Material Cost 2-3
Table 2.3-5 – Underground Material Cost 2-4
Table 2.3-6 – Overhead Construction Labor and Fleet Cost 2-4 Table 2.3-7 – Underground Construction Labor and Fleet Cost 2-4 Banning Electric Utility Demand Forecast Table 3-2
Banning Electric Utility Non-Coincident System Peak Forecast Chart 3-3 Banning Electric Utility Coincident System Forecast Chart 3-4 Conceptual Banning Electric Utility Coincident System Forecast Chart 3-5 Banning Electric Utility MWH Purchases Chart 3-9
San Gorgonio Total kW Demand Chart 3-10
Midway Total kW Demand Chart 3-11
22nd Street Total kW Demand Chart 3-12
Stagecoach Total kW Demand Chart 3-13
Ivy Total kW Demand Chart 3-14
Sunset Total kW Demand Chart 3-15
Table 4.0-1 – Current Developments 4-1
Table 4.0-2 – Future Developments 4-1
5-Year CIP Table of Contents 5-3
Table 5.2.3-1 – Conductor Material Cost 5-8
Table 5.2.3-2 Pole Material Cost 5-8
Table 5.2.3-3 Transformer Material Cost 5-9
Table 5.2.3-4 Framing Units Material Cost 5-9
Table 5.2.3-5 Underground Material Cost 5-10
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost 5-10 Table 5.2.3-7 Underground Construction Labor and Fleet Cost 5-10 Banning Electric Utility Demand Forecast Table 5-12
Banning Electric Utility Non-Coincident System Peak Forecast Chart 5-13 Banning Electric Utility Coincident System Forecast Chart 5-14 Conceptual Banning Electric Utility Coincident System Forecast Chart 5-15 Banning Electric Utility MWH Purchases Chart 5-19
San Gorgonio Total kW Demand Chart 5-20
Midway Total kW Demand Chart 5-21
22nd Street Total kW Demand Chart 5-22
Stagecoach Total kW Demand Chart 5-23
Ivy Total kW Demand Chart 5-24
Sunset Total kW Demand Chart 5-25
Table 5.4-1 – Overhead Maintenance Program Costs 5-26
Table 5.5-1 – Capital Maintenance Project Costs 5-27
Table 5.6-1 – Substation Capacity Analysis 5-46
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TABLE OF CONTENTS
Image 5.7-1 – CIP Project 1 5-48
Image 5.7-2 – CIP Project 2 5-49
Image 5.7-3 – CIP Project 3 5-50
Image 5.7-4 – CIP Project 4 5-51
Image 5.7-5 – CIP Project 5 5-52
Image 5.7-6 – CIP Project 6 5-53
Image 5.7-7 – CIP Project 7 5-54
Image 5.7-8 – CIP Project 8 5-55
Image 5.7-9 – CIP Project 9 5-56
Image 5.7-10 – CIP Project 10 5-57
Image 5.7-11 – CIP Project 11 5-58
Image 5.7-12 – CIP Project 12 5-59
Image 5.7-13 – CIP Project 13 5-60
Image 5.7-14 – CIP Project 14 5-61
Image 5.7-15 – CIP Project 15 5-62
Image 5.7-16 – CIP Project 16 5-63
Image 5.7-17 – CIP Project 17 5-64
Image 5.7-18 – CIP Project 18 5-65
Image 5.7-19 – CIP Project 19 5-66
Image 5.7-20 – CIP Project 20 5-67
Image 5.7-21 – CIP Project 21 5-68
Image 5.7-22 – CIP Project 22 5-69
Image 5.7-23 – CIP Project 23 5-70
Image 5.7-24 – CIP Project 24 5-71
Image 5.7-25 – CIP Project 25 5-72
Image 5.7-26 – CIP Project 26 5-73
Image 5.7-27 – CIP Project 27 5-74
Table 5.8-1 – Total 5-Year CIP Cost Estimate 5-75
Table 6.1-1 – Overhead Maintenance Program Costs 2031 thru 2035 6-1 Table 6.1-2 – Overhead Maintenance Program Costs 2036 thru 2040 6-2 Table 6.1-3 – Overhead Maintenance Program Costs 2041 thru 2045 6-2 Table 6.2-1 – Capital Maintenance Project Costs 6-3
Table 6.3-1 – Substation Capacity Analysis 6-4
Image 6.4-1 – ESMP Project 1 6-6
Image 6.4-2 – ESMP Project 2 6-7
Image 6.4-3 – ESMP Project 3 6-8
Image 6.4-4 – ESMP Project 4 6-9
Image 6.4-5 – ESMP Project 5 6-10
Image 6.4-6 – ESMP Project 6 6-11
Image 6.4-7 – ESMP Project 7 6-12
Image 6.4-8 – ESMP Project 8 6-13
Image 6.4-9 – ESMP Project 9 6-14
Image 6.4-10 – ESMP Project 10 6-15
Image 6.4-11 – ESMP Project 11 6-16
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Image 6.4-12 – ESMP Project 12 6-17
Image 6.4-13 – ESMP Project 13 6-18
Image 6.4-14 – ESMP Project 14 6-19
Image 6.4-15 – ESMP Project 15 6-20
Image 6.4-16 – ESMP Project 16 6-21
Image 6.4-17 – ESMP Project 17 6-22
Image 6.4-18 – ESMP Project 18 6-23
Image 6.4-19 – ESMP Project 19 6-24
Image 6.4-20 – Feeder Plan for CKT’s 75, 76, and 78 6-25 Image 6.4-21 – ESMP Project 20 6-26
Image 6.4-22 – ESMP Project 21 6-27
Image 6.4-23 – ESMP Project 22 6-28
Image 6.4-24 – ESMP Project 23 6-29
Image 6.4-25 – ESMP Project 24 6-30
Image 6.4-26 – ESMP Project 25 6-31
Image 6.4-27 – ESMP Project 26 6-32
Image 6.4-28 – ESMP Project 27 6-33
Image 6.4-29 – ESMP Project 28 6-34
Image 6.4-30 – ESMP Project 29 6-35
Image 6.4-31 – ESMP Project 30 6-36
Image 6.1-32 – Smith Creek Feeder Plan 6-36
Table 6.5-1 – 15-Year ESMP Cost Estimate (2031-2035) 6-37 Table 6.5-1 – 15-Year ESMP Cost Estimate (2036-2040) 6-38 Table 6.5-1 – 15-Year ESMP Cost Estimate (2040-2045) 6-39 Table 7.4-1 – 2026-2045 ESMP Cost Estimate 7-2
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1.0 - EXECUTIVE SUMMARY

1.1 - Introduction
The City of Banning owns the utility that provides electric service to Banning, California and the electric utility is maintained by Banning Electric Utility (BEU). Originally established in 1913 as a private utility, the City of Banning purchased the electric utility in 1922 and has been providing electric service to its residents since that time. Banning’s energy resource base includes portions of nuclear, geothermal, solar, landfill gas-to-energy, and hydro generating plants, that provide the majority of electricity required to meet the system peak demand.

Through an agreement with Southern California Edison Company (SCE), the BEU system utilizes SCE’s transmission system in bringing power from the California Independent System Operator (“CAISO”) controlled high voltage transmission grid to the BEU distribution system at the Banning Substation.

The City of Banning supports clean-energy and is committed to additional renewable energy resources to its already diverse portfolio. BEU has met and/or exceeded the renewable energy requirements of Compliance Period #1, Compliance Period #2, and Compliance Period #3 of the State’s Renewable Portfolio Standard (RPS) program. The Utility was 81 percent renewable in 2022, already exceeding the current State mandate of 60 percent by 2030.

BEU is a member of the Southern California Public Power Authority (SCPPA) enjoying the benefits of joint action through cost effective planning, construction, management, and operations of electrical energy resources.

1.2 - Purpose of Study
This Electric Service Master Plan (ESMP) is a report prepared by Finley Engineering Company, Inc. (FEC) based on an analysis and review of the historical system growth and operation to determine projections of future growth, recommendations for capital improvements, and scheduled system maintenance that will insure the continued economical and reliable operation of the system over the ensuing 20-year period.

The analysis was completed in two parts. The first 5-year analysis was completed as the Capital Improvement Plan (CIP) and includes projects and recommendations determined from the analysis, Capital Improvements specified by BEU, and Capital Maintenance also specified by BEU. This CIP will be presented to the City Council as the actual construction plan for the next 5 years. The 15 year ESMP analysis was completed as a guideline for determining the future system performance and improving system capacity for expansion.

1.3 – Existing System Review
BEU maintains three, 34.5 kV sub-transmission circuits totaling approximately eighteen miles which feed six distribution substations.

These six distribution substations have approximately 27 circuits feeding 147 miles of overhead and underground distribution line with an operating voltage of 7.2/12.5 kV. An estimated 47% of the total distribution line is underground.
1-1
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Along these distribution lines, BEU serves approximately 15,570 consumer meters. In 2024, the BEU system experienced a coincident summer peak demand of 55.1 MW and a winter peak demand of 22.3 MW. Historically, the BEU system is a summer peaking system with the summer peak more than double the winter peak. Also in 2024, BEU purchased approximately 157,000 MWH’s through its portfolio of long-term power purchase agreements as well as purchases from the CAISO wholesale markets, distributed among the membership of Residential, Small Commercial, Medium Commercial, Industrial, Security Lighting, Street Lighting, and Well Service customers.

1.4 – Total ESMP Cost Estimate
Table 1.4-1 – Total ESMP Cost Estimate
2026-2045 Electric Service Master Plan
5-year CIP 15-Year ESMP Totals
OH Maintenance Program
Total Cost $4,058,438 $23,968,742 $28,027,180
CIAC $0 $0 $0
BEU Funding Cost $4,058,438 $23,968,742 $28,027,180
Capital-Maintenance Projects
Total Cost $20,784,500 $8,350,000 $29,134,500
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $11,490,750 $5,350,000 $16,840,750
System Improvement Projects
Total Cost $2,805,700 $11,539,300 $14,345,000
CIAC $0 $0 $0
BEU Funding Cost $2,805,700 $11,539,300 $14,345,000
Total ESMP Cost
Total Cost $27,648,638 $43,858,042 $71,506,680
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $18,354,888 $40,858,042 $59,212,930
Of the total cost, 47% is for the OH Maintenance Program, 28% is for Capital Maintenance Projects, and 24% is for System Improvement Projects.
1-2
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2026-2045 ELECTRIC SERVICE MASTER PLAN

2.0 – SYSTEM PLANNING CRITERIA

2.1 - Distribution System Planning Criteria
The distribution projects contained in this ESMP are recommended based upon the following planning criteria.
a. With an assumed delivered voltage of 125 volts (1.041 per unit on a 120 volt base) during peak load conditions, the design minimum allowable voltage at the primary terminals of any distribution transformer shall be 118 volts (0.98 per unit on a 120 volt base). b. Voltage regulators and step transformers will be upgraded when projected peak loads exceed 85% of the device’s rating.
c. Sectionalizing devices will be upgraded when projected peak loads exceed 70% of the device’s continuous current rating.
d. Primary conductors on the 7.2/12.5 kV and below distribution system will be upgraded when projected peak loads exceed 60% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 60% of the conductor’s thermal rating
e. Primary conductors on the 34.5 kV sub-transmission system will be upgraded when projected peak loads exceed 90% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 90% of the conductor’s thermal rating
f. Single-phase primary voltage lines will be limited to 35 amps maximum loading. g. The power factor at the delivery point under peak loading conditions is desired to be no less than 95%. The off-peak power factor should preferably be maintained between 95% lagging and 95% leading. This criterion is subject to the cost of the installation of capacitors, switches, and controls vs. the cost of kilowatt (kW) loss reduction.

2.1.1 - Distribution System Design Criteria
The following design criteria was considered when determining projects contained in this ESMP. a. Feeder current balance will be maintained at plus or minus 20% of the average per phase loading during peak conditions. This criterion may be relaxed in areas where it could impose unnecessary or premature costs.
b. Conductor sizes will be economically sized but may be modified to conform to BEU’s standard conductor sizes.
c. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any load voltage or high conductor loading. d. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any high single-phase loading. For areas where there is no backfeed or load switch solution, additional conductors will be added to allow for phase balancing. 2-1
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CITY OF BANNING ELECTRIC UTILITY
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e. Relocation of existing line sections will be considered where inaccessibility impedes the maintenance of line sections or jeopardizes the service or reliability of line sections.

2.2 – Substation Planning Criteria
The substation projects contained in this ESMP are recommended based upon the following planning criteria.
a. Substation transformers will limited to 95% of the max kVA rating of the transformer. The following improvements will be considered in the event the load exceeds 95% of the max kVA rating:
a. Load switching to adjacent substations
b. Upgrade of existing transformer
c. Installation of an additional transformer in the existing substation d. Construction of a new substation

2.3 – Basis of Cost Estimates
The following tables for material and labor costs were used to determine system improvement project costs. The costs were taken from actual prices provided by BEU as well as prices received by FEC from other sources.

Table 2.3-1 Conductor Material Cost
Conductor (price per foot)
OH Conductor UG Conductor
#2 Copper $1.31 1/0 AL, 15 kV $2.03
#2 ACSR $0.26 1/0 CU, 15 kV $10.98
#4 ACSR $0.15 1/0 CU, 35 kV $8.47
1/0 ACSR $0.30 4/0 CU $6.95
4/0 Copper $3.11 4/0 AL $4.97
4/0 ACSR $0.80 350 CU $7.53
336 ACSR $1.62 750 AL $13.38
Table 2.3-2 Pole Material Cost
Pole Price per unit Pole Price per unit
35' Douglas Fir, H2 $1,269.30 35’ Wood, Class 2 $1,067.38 40’ Wood, Class 2 $766.35
45' Douglas Fir, H2 $1,771.08 45’ Wood, Class 2 $953.80 50’ Wood, Class 2 $1,135.73
55' Douglas Fir, H2 $2,889.48 55’ Wood, Class 2 $918.72 60' Douglas Fir, H2 $2,945.89 60’ Wood, Class 2 $1,362.29 2-2
16925

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 2.3-3 Transformer Material Cost
Transformer Price per unit
10 kVA O.H. Transformer S-Type 7,200 $500.00
15 kVA 7,200, 120/240 DV S-Type $645.42
25 kVA 7,200, 120/240 DV S-Type $919.16
37 kVA 7,200, 120/240 DV S-Type $1,496.65
50 kVA 7,200 120/240 $3,992.05
75 kVA 3Ø 12,470/7,200 120/208 $6,023.22
300 kVA DV $8,583.61
750 kVA 3Ø 12,470/7,200 $14,626.30
1,000 kVA 3Ø 12,470/7,200 DV $10,809.48
2,500 kVA 3Ø 12,470/7,200 277/480 $34,539.92
25 kVA 1Ø 12,470/7,200 120/240 Pdmnt $3,685.34

37.5 kVA 1Ø 12,400/7,200 DV Pdmnt $1,988.01
75 kVA 1Ø 12,470/7,200 120/240 Pdmnt $7,110.42
300 kVA 3Ø 12,470/4,160 DV Pdmnt 208/120 $13,547.15
500 kVA 3Ø Pdmnt $10,442.65
1,500 kVA DV 3Ø Pdmnt 277/480 $31,037.04
Table 2.3-4 Framing Units Material Cost
Framing Unit Price per unit
A1.3P $75.32
A1.11P $493.46
A5.2G $286.41
A3.1 $78.74
A6.21 $1,080.29
G1.2 $317.41
G1.2 $1,318.96
A5.1 $195.12
A5.21 $888.35
(A4.1) $255.90
G1.3 $433.79
G1.3 $1,127.02
C1.11 $628.33
C1.81G $1,592.53
C1.11,A5.21 $1,516.68
C5.82G $3,472.80
C3.1 $208.96
C3.1,A5.1 $404.08
C3.1,A5.21 $1,097.31
C3.1, C5.1 $376.78
C5.1 $167.82
C5.1,A5.1 $362.94
C5.1,A5.21 $1,056.17
2-3
17026

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 2.3-5 Underground Material Cost
Material Price per unit
Light Duty Secondary Box $78.42
Light Duty Secondary Lid $83.43
4" PVC SCH 40 (per foot) $1.69
1/0 AL U/G (per foot) $4.75
Service Entrance Sleeve $0.45
Deadend Shoe Small $8.58
Power Solve (Pulling Lube) $58.98
Table 2.3-6 Overhead Construction Labor and Fleet Cost
Units
(hr.)
Unit Cost
(per hr.)
Utility Bed P/U 1 ton (Foreman) (2 hrs. per connection) 4 $27.78 2 Person Lift (Bucket Truck) 55' (2 hrs. per connection) 2 $51.68 4 Person Crew 4 $466.73
3 Person Crew (2 hours per connection) 4 $352.02
2 Person Crew 2 $237.31
Electrical Engineering Supervisor (0.5 hrs. per connection) 1 $125.98 Electric Service Planning Supervisor (0.5 hrs. per connection) 1 $127.97 GIS Technician (1 hr. per connection) 2 $59.21
For overhead line, project cost estimates are based on an average of construction 1 mile of line per month with average span lengths at 150’.

Table 2.3-7 Underground Construction Labor and Fleet Cost Labor Price per hr.
4 Person Line Crew $466.73
Powerline Crew Superintendent $135.93
Fleet Price per hr.

Dump Truck $55.98
Utility Bed P/U 1 ton (Foreman) (3) $27.78
Digger Derrick $48.77
Wire Puller $24.98
Reel Trailer $24.98
Backhoe $23.95
For underground line, project estimates are based on an average construction of 1 month to trench, lay conduit, pull wire and terminate, and backfill 300’.

Engineering (10%) and contingency (5%) were also added for each cost estimate. 2-4
17127

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

3.0 LOAD FORECAST
The demand forecast was prepared to project the summer and winter kW demand per substation area as well as the total system demand for the City of Banning for the 2026-2045 ESMP period.

The historical non-coincident substation demands as well as the historical coincident system demands were provided by BEU and used as the basis for the forecast. BEU also provided insight into new load additions that are in some sort of application or planning process and were used in the conceptual forecast.

Additional factors that were considered when reviewing the historical peaks include temporary load switching between substations, construction of new substations with permanent load switching, and removal and/or replacement of existing substations.

Along with new load additions, considerations were also made for the addition of EV chargers at new subdivision locations.

This forecast was used to run voltage drop and load flow analysis to determine system improvements required to reliably serve the City of Banning’s existing consumers and allow for future consumer growth.

It is projected that the BEU system will reach a non-coincident peak of 110,556 kW in the summer of 2045 and 81,410 kW in the winter of 2045. It is also projected that the BEU system will reach a coincident peak of 90,738 kW in the summer of 2045 and 75,580 kW in the winter of 2045.

A separate conceptual forecast was created to include new load additions that are in some state of application or planning process. It is projected that the BEU system will reach a conceptual non-coincident peak of 176,165 kW in the summer of 2045 and 161,007 kW in the winter of 2045.

As part of the historical review, MWH purchases were also reviewed and a forecast was determined. It is projected that the BEU system will have an annual coincident purchase of 272,571 MWH’s by 2045.

A graphical representation of the individual substation demand forecast as well as the total system coincident demand, non-coincident demand, conceptual non-coincident demand and MWH purchases is included following this page.
3-1
17228

BANNING ELECTRIC UTILTIY
2026-2045 ESMP SYSTEM FORECAST
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 San Gorgonio Total
S 16,425 17,079 16,472 9,131 4,958 16,500 16,830 17,167 17,510 17,860 18,217 18,582 18,953 19,332 19,719 20,113 20,516 20,926 21,345 21,771 22,207 22,651 23,104 23,566 24,037 24,518 2.0% W 15,022 12,746 11,267 7,193 3,739 15,000 15,300 15,606 15,918 16,236 16,561 16,892 17,230 17,575 17,926 18,285 18,651 19,024 19,404 19,792 20,188 20,592 21,004 21,424 21,852 22,289 2.0% Cannabis Cultivation 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 Yoshinoya 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 S 16,425 17,079 16,472 9,131 4,958 19,748 20,078 20,415 20,758 21,108 21,465 21,830 22,201 22,580 22,967 23,361 23,764 24,174 24,593 25,019 25,455 25,899 26,352 26,814 27,285 27,766 1.7% W 15,022 12,746 11,267 7,193 3,739 18,248 18,548 18,854 19,166 19,484 19,809 20,140 20,478 20,823 21,174 21,533 21,899 22,272 22,652 23,040 23,436 23,840 24,252 24,672 25,100 25,537 1.7% Midway Total
S 13,541 13,649 14,272 17,082 15,786 15,052 15,458 15,876 16,304 16,745 17,197 17,661 18,138 18,628 19,131 19,647 20,178 20,722 21,282 21,856 22,447 23,053 23,675 24,314 24,971 25,645 2.7% W 10,384 9,247 7,788 6,868 10,715 9,663 9,924 10,192 10,467 10,750 11,040 11,338 11,644 11,958 12,281 12,613 12,953 13,303 13,662 14,031 14,410 14,799 15,199 15,609 16,031 16,463 2.7% Airport
S 365 370 360 32 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% W 389 389 280 23 22 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% 22nd Street
S 10,233 10,319 9,736 10,585 11,240 10,670 10,787 10,906 11,026 11,147 11,270 11,394 11,519 11,646 11,774 11,904 12,034 12,167 12,301 12,436 12,573 12,711 12,851 12,992 13,135 13,280 1.1% W 8,140 6,529 6,105 6,567 8,018 8,210 8,300 8,392 8,484 8,577 8,672 8,767 8,863 8,961 9,059 9,159 9,260 9,362 9,465 9,569 9,674 9,781 9,888 9,997 10,107 10,218 1.1% Stagecoach
S 0 0 0 6,634 8,040 6,700 6,834 6,971 7,110 7,252 7,397 7,545 7,696 7,850 8,007 8,167 8,331 8,497 8,667 8,841 9,017 9,198 9,382 9,569 9,761 9,956 2.0% W 0 0 0 3,616 7,955 3,800 3,876 3,954 4,033 4,113 4,196 4,279 4,365 4,452 4,541 4,632 4,725 4,819 4,916 5,014 5,114 5,217 5,321 5,427 5,536 5,647 2.0% Ivy
S 0 0 5,308 7,206 8,333 5,400 5,508 5,618 5,731 5,845 5,962 6,081 6,203 6,327 6,453 6,583 6,714 6,849 6,985 7,125 7,268 7,413 7,561 7,713 7,867 8,024 2.0% W 0 0 4,493 4,890 6,235 4,500 4,590 4,682 4,775 4,871 4,968 5,068 5,169 5,272 5,378 5,485 5,595 5,707 5,821 5,938 6,056 6,178 6,301 6,427 6,556 6,687 2.0% Morongo Health Clinic 0 0 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 S 0 0 5,308 7,206 8,333 5,400 5,508 6,254 6,367 6,481 6,598 6,717 6,839 6,963 7,089 7,219 7,350 7,485 7,621 7,761 7,904 8,049 8,197 8,349 8,503 8,660 2.4% W 0 0 4,493 4,890 6,235 4,500 4,590 5,318 5,411 5,507 5,604 5,704 5,805 5,908 6,014 6,121 6,231 6,343 6,457 6,574 6,692 6,814 6,937 7,063 7,192 7,323 2.5% Sunset
S 8,140 8,099 9,586 11,441 14,821 10,439 10,857 11,291 11,742 12,212 12,701 13,209 13,737 14,286 14,858 15,452 16,070 16,713 17,382 18,077 18,800 19,552 20,334 21,147 21,993 22,873 4.0% W 6,716 5,803 5,037 8,299 11,443 6,319 6,572 6,835 7,108 7,392 7,688 7,996 8,315 8,648 8,994 9,354 9,728 10,117 10,522 10,942 11,380 11,835 12,309 12,801 13,313 13,846 4.0% Crestwood Communities 432 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 Vista Robles KB homes 0 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 S 8,140 8,099 9,586 11,441 14,821 10,871 13,233 13,667 14,118 14,588 15,077 15,585 16,113 16,662 17,234 17,828 18,446 19,089 19,758 20,453 21,176 21,928 22,710 23,523 24,369 25,249 4.3% W 6,716 5,803 5,037 8,299 11,443 6,751 8,948 9,211 9,484 9,768 10,064 10,372 10,691 11,024 11,370 11,730 12,104 12,493 12,898 13,318 13,756 14,211 14,685 15,177 15,689 16,222 4.5% Alola
S 2,929 2,370 1,646 372 0000000000000000000000 0.0%
W 2,377 708 782 336 0000000000000000000000 0.0%
Banning Electric Utility Non-Coincident System Peak Forecast S 51,632 51,885 57,380 62,482 63,207 68,441 71,898 74,088 75,683 77,322 79,004 80,732 82,507 84,330 86,202 88,126 90,103 92,134 94,221 96,367 98,571 100,837 103,167 105,562 108,024 110,556 2.4% W 43,029 35,422 35,752 37,792 48,126 51,172 54,186 55,919 57,045 58,200 59,385 60,600 61,847 63,127 64,440 65,788 67,172 68,592 70,050 71,546 73,083 74,661 76,281 77,945 79,654 81,410 2.3% Banning Electric Utility System Coincident Forecast
S 51,197 49,751 52,667 51,096 55,143 56,467 57,822 59,210 60,631 62,086 63,576 65,102 66,664 68,264 69,902 71,580 73,298 75,057 76,858 78,703 80,592 82,526 84,507 86,535 88,612 90,738 2.4% W 40,752 25,776 34,719 32,262 46,883 47,962 49,065 50,193 51,348 52,529 53,737 54,973 56,237 57,530 58,854 60,207 61,592 63,009 64,458 65,940 67,457 69,009 70,596 72,219 73,881 75,580 2.3% Conceptual Banning Electric Utility System Coincident Forecast S 51,197 49,751 52,667 51,096 55,143 56,467 58,962 61,201 69,810 76,184 86,777 100,472 109,135 120,377 129,082 137,336 145,321 153,347 157,527 161,751 166,019 167,953 169,934 171,962 174,039 176,165 5.9% W 40,752 25,776 34,719 32,262 46,883 47,962 50,205 52,185 60,527 66,627 76,938 90,343 98,708 109,643 118,034 125,963 133,615 141,299 145,127 148,988 152,884 154,436 156,023 157,646 159,308 161,007 6.2% Bridge-Morongo Logistics 0000 1,031 1,991 2,858 3,344 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 Sunset Crossroads 0 0 0 2,712 2,712 6,967 10,213 10,561 13,639 14,439 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 Rancho San Gorgonio 0 0 0 3,888 7,776 11,664 15,552 19,440 23,328 27,216 31,104 34,992 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 Mission Heights 000000 2,379 4,758 7,137 9,516 11,895 14,274 16,653 19,032 21,411 23,790 23,790 23,790 23,790 23,790 23,790 First Hathaway Logistics 0 0 0 0 0 0 471 471 471 471 471 471 471 471 471 471 471 471 471 471 471 Banning Commerce Center 0 0 0 0 0 0 438 438 438 438 438 438 438 438 438 438 438 438 438 438 438 WEKA 007777777777777777777
Charles St. CDRE 0 0 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 KCB Towers 0 0 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 Pallet Yard 007777777777777777777
First Lincoln Logistics 0 0 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 Brown Strauss 0 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 Wyndam Micro Hotel 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 DR Horton 0 0 588 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 Atwell Large Retail 0 0 0 0 0 0 880 880 880 880 880 880 880 880 880 880 880 880 880 880 880 2025-2045
Annual
Growth Rate
Historical Forecast
Peak kW Demand
3-2
17329
.00

80.0060.0040.0020.00
120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY NON-COINCIDENT SYSTEM PEAK FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
3-3
17430
.00

90.0080.0070.0060.0050.0040.0030.0020.0010.00
100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
3-4
17531
.00

80.0060.0040.0020.00
200.00180.00160.00140.00120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

CONCEPTUAL BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

6.2% ANNUAL GROWTH
RATE

SUMMER-FORECAST

5.9% ANNUAL GROWTH
RATE
3-5
17632

BANNING ELECTRIC UTILITY
2026-2045 ESMP NON-COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 11,577 21.27 12,259 22.52 12,651 23.24 12,906 23.71 13,167 24.19 13,435 24.68 13,710 25.19 Feb 10,470 21.33 11,086 22.58 11,441 23.31 11,671 23.78 11,907 24.26 12,150 24.75 12,399 25.26 Mar 10,870 20.69 11,511 21.91 11,879 22.61 12,118 23.07 12,363 23.54 12,615 24.01 12,873 24.51 Apr 13,733 32.53 14,427 34.18 14,867 35.22 15,187 35.98 15,515 36.76 15,853 37.56 16,200 38.38 May 15,631 37.92 16,420 39.84 16,920 41.05 17,285 41.94 17,659 42.85 18,043 43.78 18,438 44.74 Jun 18,497 56.73 19,432 59.59 20,023 61.41 20,455 62.73 20,897 64.09 21,352 65.48 21,819 66.92 Jul 25,788 65.86 27,090 69.19 27,915 71.29 28,517 72.83 29,134 74.40 29,768 76.02 30,419 77.69 Aug 26,719 68.44 28,069 71.90 28,923 74.09 29,546 75.68 30,186 77.32 30,843 79.00 31,517 80.73 Sep 21,335 64.10 22,413 67.34 23,096 69.39 23,593 70.88 24,104 72.42 24,628 73.99 25,167 75.61 Oct 19,525 51.17 20,675 54.19 21,336 55.92 21,766 57.05 22,206 58.20 22,658 59.38 23,122 60.60 Nov 10,787 21.08 11,423 22.32 11,788 23.04 12,025 23.50 12,269 23.98 12,518 24.46 12,775 24.97 Dec 12,073 22.02 12,784 23.31 13,193 24.06 13,458 24.54 13,731 25.04 14,010 25.55 14,297 26.07 TOTAL: 197,005 207,588 214,032 218,526 223,138 227,873 232,734 Summer Peak (MW) 68.44 71.90 74.09 75.68 77.32 79.00 80.73 Winter Peak (MW) 51.17 54.19 55.92 57.05 58.20 59.38 60.60 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 13,992 25.71 14,282 26.24 14,579 26.79 14,884 27.35 15,197 27.92 15,518 28.51 15,848 29.12 Feb 12,654 25.78 12,916 26.31 13,184 26.86 13,460 27.42 13,743 28.00 14,034 28.59 14,332 29.20 Mar 13,138 25.01 13,410 25.53 13,689 26.06 13,975 26.60 14,269 27.16 14,571 27.74 14,880 28.33 Apr 16,556 39.22 16,922 40.09 17,297 40.98 17,683 41.89 18,080 42.83 18,488 43.80 18,907 44.79 May 18,843 45.72 19,259 46.73 19,687 47.77 20,126 48.83 20,578 49.93 21,042 51.05 21,518 52.21 Jun 22,299 68.39 22,791 69.90 23,297 71.45 23,817 73.04 24,352 74.68 24,901 76.37 25,465 78.10 Jul 31,087 79.39 31,774 81.15 32,480 82.95 33,205 84.80 33,950 86.70 34,715 88.66 35,501 90.67 Aug 32,210 82.51 32,922 84.33 33,653 86.20 34,404 88.13 35,176 90.10 35,969 92.13 36,783 94.22 Sep 25,720 77.27 26,288 78.98 26,872 80.74 27,472 82.54 28,088 84.39 28,721 86.29 29,372 88.25 Oct 23,598 61.85 24,086 63.13 24,587 64.44 25,102 65.79 25,630 67.17 26,171 68.59 26,728 70.05 Nov 13,038 25.48 13,307 26.01 13,584 26.55 13,868 27.10 14,160 27.67 14,459 28.26 14,767 28.86 Dec 14,591 26.61 14,893 27.16 15,203 27.73 15,521 28.31 15,847 28.90 16,182 29.51 16,526 30.14 TOTAL: 237,725 242,850 248,113 253,518 259,069 264,770 270,627 Summer Peak (MW) 82.51 84.33 86.20 88.13 90.10 92.13 94.22 Winter Peak (MW) 61.85 63.13 64.44 65.79 67.17 68.59 70.05 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 16,187 29.74 16,534 30.38 16,891 31.03 17,258 31.71 17,634 32.40 18,021 33.11 18,418 33.84 Feb 14,638 29.82 14,953 30.46 15,275 31.12 15,607 31.79 15,947 32.49 16,297 33.20 16,656 33.93 Mar 15,198 28.93 15,525 29.55 15,860 30.19 16,204 30.85 16,558 31.52 16,921 32.21 17,294 32.92 Apr 19,337 45.81 19,779 46.86 20,234 47.93 20,702 49.04 21,182 50.18 21,676 51.35 22,184 52.55 May 22,008 53.40 22,512 54.62 23,029 55.88 23,561 57.17 24,108 58.49 24,671 59.86 25,249 61.26 Jun 26,044 79.88 26,640 81.70 27,253 83.58 27,882 85.51 28,530 87.50 29,195 89.54 29,879 91.64 Jul 36,310 92.73 37,140 94.85 37,994 97.03 38,872 99.27 39,774 101.58 40,702 103.95 41,656 106.38 Aug 37,621 96.37 38,482 98.57 39,366 100.84 40,276 103.17 41,211 105.56 42,172 108.02 43,160 110.56 Sep 30,041 90.26 30,728 92.32 31,434 94.44 32,161 96.63 32,907 98.87 33,675 101.17 34,464 103.55 Oct 27,299 71.55 27,885 73.08 28,487 74.66 29,105 76.28 29,740 77.95 30,392 79.65 31,062 81.41 Nov 15,082 29.47 15,406 30.11 15,739 30.76 16,080 31.43 16,431 32.11 16,791 32.82 17,161 33.54 Dec 16,879 30.78 17,242 31.44 17,614 32.12 17,996 32.82 18,389 33.54 18,792 34.27 19,206 35.03 TOTAL: 276,644 282,826 289,178 295,705 302,412 309,305 316,390 Summer Peak (MW) 96.37 98.57 100.84 103.17 105.56 108.02 110.56 Winter Peak (MW) 71.55 73.08 74.66 76.28 77.95 79.65 81.41 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
3-6
17733

BANNING ELECTRIC UTILITY
2026-2045 ESMP COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,100 20.39 11,356 20.86 11,617 21.34 11,884 21.83 12,157 22.34 12,437 22.85 Feb 9,813 19.99 10,038 20.45 10,269 20.92 10,506 21.40 10,747 21.89 10,994 22.40 11,247 22.91 Mar 10,188 19.40 10,423 19.84 10,662 20.30 10,908 20.76 11,158 21.24 11,415 21.73 11,678 22.23 Apr 11,331 26.84 11,603 27.49 11,881 28.15 12,166 28.82 12,458 29.51 12,757 30.22 13,063 30.95 May 12,896 31.29 13,205 32.04 13,522 32.81 13,847 33.60 14,179 34.40 14,519 35.23 14,868 36.07 Jun 15,261 46.80 15,627 47.93 16,002 49.08 16,386 50.25 16,780 51.46 17,182 52.70 17,595 53.96 Jul 21,276 54.34 21,787 55.64 22,309 56.98 22,845 58.34 23,393 59.74 23,955 61.18 24,529 62.65 Aug 22,044 56.47 22,573 57.82 23,115 59.21 23,670 60.63 24,238 62.09 24,820 63.58 25,415 65.10 Sep 17,603 52.89 18,025 54.16 18,458 55.45 18,901 56.79 19,354 58.15 19,819 59.54 20,294 60.97 Oct 18,300 47.96 18,721 49.06 19,151 50.19 19,592 51.35 20,042 52.53 20,503 53.74 20,975 54.97 Nov 10,110 19.76 10,343 20.21 10,581 20.68 10,824 21.15 11,073 21.64 11,328 22.14 11,588 22.65 Dec 11,315 20.64 11,575 21.11 11,842 21.60 12,114 22.09 12,393 22.60 12,678 23.12 12,969 23.65 TOTAL: 170,987 175,020 179,149 183,374 187,700 192,127 196,659 Summer Peak (MW) 56.47 57.82 59.21 60.63 62.09 63.58 65.10 Winter Peak (MW) 47.96 49.06 50.19 51.35 52.53 53.74 54.97 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 12,723 23.38 13,016 23.91 13,315 24.46 13,621 25.03 13,935 25.60 14,255 26.19 14,583 26.79 Feb 11,506 23.44 11,771 23.98 12,041 24.53 12,318 25.09 12,602 25.67 12,891 26.26 13,188 26.86 Mar 11,946 22.74 12,221 23.26 12,502 23.80 12,790 24.35 13,084 24.91 13,385 25.48 13,693 26.07 Apr 13,377 31.69 13,698 32.45 14,027 33.23 14,363 34.03 14,708 34.84 15,061 35.68 15,422 36.54 May 15,225 36.94 15,590 37.83 15,964 38.73 16,347 39.66 16,740 40.62 17,142 41.59 17,553 42.59 Jun 18,017 55.26 18,449 56.58 18,892 57.94 19,346 59.33 19,810 60.75 20,285 62.21 20,772 63.71 Jul 25,118 64.15 25,721 65.69 26,338 67.27 26,970 68.88 27,618 70.53 28,281 72.23 28,959 73.96 Aug 26,025 66.66 26,650 68.26 27,289 69.90 27,944 71.58 28,615 73.30 29,302 75.06 30,005 76.86 Sep 20,781 62.44 21,280 63.94 21,791 65.47 22,314 67.04 22,849 68.65 23,398 70.30 23,959 71.98 Oct 21,457 56.24 21,951 57.53 22,456 58.85 22,972 60.21 23,501 61.59 24,041 63.01 24,594 64.46 Nov 11,855 23.17 12,128 23.70 12,406 24.25 12,692 24.80 12,984 25.37 13,282 25.96 13,588 26.55 Dec 13,268 24.20 13,573 24.75 13,885 25.32 14,204 25.90 14,531 26.50 14,865 27.11 15,207 27.73 TOTAL: 201,298 206,047 210,907 215,882 220,975 226,188 231,523 Summer Peak (MW) 66.66 68.26 69.90 71.58 73.30 75.06 76.86 Winter Peak (MW) 56.24 57.53 58.85 60.21 61.59 63.01 64.46 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 14,918 27.41 15,261 28.04 15,612 28.68 15,971 29.34 16,339 30.02 16,715 30.71 17,099 31.42 Feb 13,491 27.48 13,801 28.11 14,119 28.76 14,444 29.42 14,776 30.10 15,116 30.79 15,463 31.50 Mar 14,007 26.67 14,330 27.28 14,659 27.91 14,996 28.55 15,341 29.20 15,694 29.88 16,055 30.56 Apr 15,793 37.41 16,172 38.31 16,560 39.23 16,957 40.17 17,364 41.14 17,781 42.12 18,208 43.13 May 17,974 43.61 18,406 44.66 18,847 45.73 19,300 46.83 19,763 47.95 20,237 49.10 20,723 50.28 Jun 21,271 65.23 21,781 66.80 22,304 68.40 22,839 70.04 23,387 71.73 23,949 73.45 24,523 75.21 Jul 29,654 75.73 30,366 77.55 31,095 79.41 31,841 81.32 32,605 83.27 33,388 85.27 34,189 87.32 Aug 30,725 78.70 31,462 80.59 32,218 82.53 32,991 84.51 33,783 86.53 34,593 88.61 35,424 90.74 Sep 24,534 73.71 25,123 75.48 25,726 77.29 26,344 79.15 26,976 81.05 27,623 82.99 28,286 84.98 Oct 25,160 65.94 25,738 67.46 26,330 69.01 26,936 70.60 27,555 72.22 28,189 73.88 28,838 75.58 Nov 13,900 27.17 14,220 27.79 14,547 28.43 14,882 29.08 15,224 29.75 15,574 30.44 15,932 31.14 Dec 15,557 28.37 15,915 29.02 16,281 29.69 16,655 30.37 17,038 31.07 17,430 31.79 17,831 32.52 TOTAL: 236,985 242,576 248,298 254,156 260,152 266,289 272,571 Summer Peak (MW) 78.70 80.59 82.53 84.51 86.53 88.61 90.74 Winter Peak (MW) 65.94 67.46 69.01 70.60 72.22 73.88 75.58 Projected Load Data 2039-2045
Projected Load Data 2032-2038
2039 2040 2041 2042 2043 2044 2045
Projected Load Data 2025 - 2031
2032 2033 2034 2035 2036 2037 2038
2025 2026 2027 2028 2029 2030 2031
3-7
17834

BANNING ELECTRIC UTILITY
2026-2045 ESMP CONCEPTUAL COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,358 20.87 11,806 21.69 13,693 25.16 15,074 27.69 17,406 31.98 20,439 37.55 Feb 9,813 19.99 10,272 20.92 10,677 21.75 12,384 25.23 13,632 27.77 15,741 32.07 18,484 37.65 Mar 10,188 19.40 10,665 20.30 11,085 21.10 12,857 24.48 14,153 26.94 16,344 31.11 19,191 36.53 Apr 11,331 26.84 11,831 28.03 12,281 29.09 14,008 33.19 15,287 36.22 17,413 41.25 20,161 47.76 May 12,896 31.29 13,466 32.67 13,977 33.91 15,943 38.68 17,399 42.22 19,818 48.08 22,946 55.67 Jun 15,261 46.80 15,935 48.87 16,540 50.73 18,867 57.86 20,590 63.15 23,453 71.93 27,154 83.28 Jul 21,276 54.34 22,216 56.74 23,060 58.89 26,303 67.18 28,705 73.31 32,696 83.50 37,856 96.68 Aug 22,044 56.47 23,018 58.96 23,892 61.20 27,253 69.81 29,742 76.18 33,877 86.78 39,223 100.47 Sep 17,603 52.89 18,380 55.22 19,078 57.32 21,762 65.38 23,749 71.35 27,051 81.27 31,320 94.10 Oct 18,300 47.96 19,156 50.20 19,911 52.18 23,094 60.53 25,421 66.63 29,356 76.94 34,470 90.34 Nov 10,110 19.76 10,583 20.68 11,001 21.50 12,759 24.94 14,045 27.45 16,219 31.70 19,044 37.22 Dec 11,315 20.64 11,844 21.60 12,312 22.45 14,280 26.04 15,719 28.67 18,151 33.10 21,314 38.87 TOTAL: 170,987 178,725 185,621 213,204 233,515 267,525 311,603 Summer Peak (MW) 56.47 58.96 61.20 69.81 76.18 86.78 100.47 Winter Peak (MW) 47.96 50.20 52.18 60.53 66.63 76.94 90.34 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 22,332 41.03 24,806 45.58 26,704 49.06 28,498 52.36 30,229 55.54 31,967 58.73 32,833 60.32 Feb 20,195 41.14 22,433 45.70 24,149 49.19 25,772 52.50 27,337 55.69 28,909 58.89 29,692 60.49 Mar 20,968 39.92 23,291 44.34 25,073 47.73 26,758 50.94 28,383 54.03 30,016 57.14 30,829 58.69 Apr 21,899 51.88 24,155 57.22 25,902 61.36 27,558 65.29 29,160 69.08 30,771 72.90 31,610 74.88 May 24,924 60.47 27,492 66.70 29,480 71.53 31,365 76.10 33,188 80.53 35,021 84.97 35,976 87.29 Jun 29,495 90.46 32,534 99.78 34,886 106.99 37,117 113.83 39,275 120.45 41,444 127.10 42,574 130.57 Jul 41,121 105.02 45,356 115.84 48,637 124.21 51,746 132.15 54,755 139.84 57,779 147.56 59,354 151.58 Aug 42,606 109.14 46,994 120.38 50,393 129.08 53,615 137.34 56,732 145.32 59,866 153.35 61,498 157.53 Sep 34,021 102.21 37,526 112.74 40,239 120.90 42,812 128.63 45,301 136.11 47,803 143.62 49,107 147.54 Oct 37,662 98.71 41,835 109.64 45,036 118.03 48,061 125.96 50,981 133.62 53,913 141.30 55,373 145.13 Nov 20,808 40.66 23,113 45.17 24,882 48.63 26,553 51.89 28,166 55.05 29,786 58.21 30,593 59.79 Dec 23,287 42.47 25,867 47.17 27,847 50.78 29,718 54.20 31,523 57.49 33,336 60.79 34,239 62.44 TOTAL: 339,319 375,401 403,228 429,573 455,032 480,611 493,678 Summer Peak (MW) 109.14 120.38 129.08 137.34 145.32 153.35 157.53 Winter Peak (MW) 98.71 109.64 118.03 125.96 133.62 141.30 145.13 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 33,707 61.93 34,588 63.55 34,939 64.19 35,298 64.85 35,666 65.53 36,042 66.22 36,426 66.93 Feb 30,483 62.10 31,280 63.72 31,597 64.37 31,922 65.03 32,254 65.70 32,594 66.40 32,941 67.10 Mar 31,649 60.25 32,477 61.82 32,806 62.45 33,143 63.09 33,488 63.75 33,841 64.42 34,202 65.11 Apr 32,457 76.89 33,314 78.92 33,702 79.84 34,099 80.78 34,506 81.75 34,923 82.73 35,350 83.74 May 36,941 89.63 37,915 91.99 38,357 93.07 38,810 94.16 39,273 95.29 39,747 96.44 40,233 97.62 Jun 43,716 134.07 44,869 137.61 45,392 139.21 45,927 140.85 46,475 142.53 47,037 144.25 47,611 146.02 Jul 60,946 155.65 62,554 159.76 63,283 161.62 64,029 163.52 64,793 165.47 65,575 167.47 66,377 169.52 Aug 63,146 161.75 64,813 166.02 65,568 167.95 66,341 169.93 67,133 171.96 67,943 174.04 68,774 176.17 Sep 50,423 151.49 51,754 155.49 52,357 157.30 52,974 159.16 53,606 161.06 54,254 163.00 54,917 164.99 Oct 56,847 148.99 58,333 152.88 58,925 154.44 59,531 156.02 60,150 157.65 60,784 159.31 61,432 161.01 Nov 31,407 61.38 32,228 62.98 32,555 63.62 32,890 64.28 33,232 64.95 33,582 65.63 33,941 66.33 Dec 35,150 64.10 36,069 65.78 36,435 66.45 36,809 67.13 37,192 67.83 37,584 68.54 37,985 69.27 TOTAL: 506,871 520,193 525,915 531,773 537,769 543,906 550,188 Summer Peak (MW) 161.75 166.02 167.95 169.93 171.96 174.04 176.17 Winter Peak (MW) 148.99 152.88 154.44 156.02 157.65 159.31 161.01 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
3-8
17935
0 50
300250200150100
'19 '20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MWH (x1,000)
YEAR

BANNING ELECTRIC UTILTIY MWH PURCHASES

HISTORICAL

FORECAST

2.4% ANNUAL GROWTH
RATE
3-9
18036
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SAN GORGONIO TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.7% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.7% ANNUAL GROWTH
RATE
3-10
18137
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
MIDWAY TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

SUMMER-FORECAST

2.7% ANNUAL GROWTH
RATE

WINTER-FORECAST

2.7% ANNUAL GROWTH
RATE
3-11
18238
0 8,0006,0004,0002,000
14,00012,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
22ND STREET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.1% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.1% ANNUAL GROWTH
RATE
3-12
18339
0 8,0006,0004,0002,000
12,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
STAGECOACH kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
3-13
18440
0 9,0008,0007,0006,0005,0004,0003,0002,0001,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
IVY kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
3-14
18541
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SUNSET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

4.5% ANNUAL GROWTH
RATE

SUMMER-FORECAST

4.3% ANNUAL GROWTH
RATE
3-15
18642

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

4.0 – LAND USE AND POPULATION
The City of Banning is located in Riverside County and has a reported 2026 population of approximately 33,000 people which has increased by an estimated 10% since the most recent census in 2020. The annual growth rate is projected at 1.6% The BEU service area for the most part is the same as the Banning City Boundary which covers approximately 23 square miles.

The following table shows current development whose load was included in the ESMP analysis.

Table 4.0-1 – Current Developments
Development Classification Land Area (acres) Size
Atwell Subdivision Residential 1,457 14,000 + lots
Cannabis Cultivation Industrial 0.5 -
Yoshinoya Commercial - -
Morongo Health Clinic Commercial - -
Crestwood Communities Residential 5.9 19 lots
Vista Robles Homes Residential 72 140 lots
The following table shows future developments whose load was included in the ESMP analysis.

Table 4.0-2 – Future Developments
Development Classification Land Area (acres) Size
Bridge-Morongo Logistics Commercial/Industrial 509 5 buildings Sunset Crossroads Commercial/Industrial 559 6 buildings Rancho San Gorgonio Residential 710 3,600 lots
Mission Heights Residential - 2,200 lots
First Hathaway Logistics Commercial/Industrial 88 -
Banning Commerce Center Industrial 124 -
WEKA Industrial 3.4 -
Charlles St. CDRE Industrial 4.6 -
KCB Towers Industrial 4.5 -
Pallet Yard Industrial 0.3 -
First Lincoln Logistics Commercial 6.2 -
Brown Strauss Commercial 15.8 -
Wyndam Micro Hotel Residential/Commercial 1.3 -
DR Horton Residential - 98 lots
Atwell Large Retail Commercial - -
4-1
18743

CITY OF BANNING, CALIFORNIA
2026-2030 5-YEAR CAPITAL IMPROVEMENT PLAN
April 2026
Prepared by:

Finley Engineering Company, Inc.

On behalf of:

Banning Electric Utility
Contact Information:

Finley Engineering Company, Inc.

PO Box 148, 104 E. 11th Street
Lamar, MO 64795
417.682.5531
www.finleyusa.com
City of Banning
99 E. Ramsey Street
Banning, CA 92220
951.922.3100
www.banningca.gov
5-1
18844

ENGINEERS CERTIFICATION
I, Christopher Adam Smart, P.E., herby certify that this 2026-2030 5-Year Capital Improvement Plan was prepared by me or under my direct Supervision and that I am a duly Licensed Professional Engineer under the laws of the state of California, license number E 25395.

X
5-2
18945

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

TABLE OF CONTENTS
Section Page

5.0 - 5-Year Construction Improvement Plan (CIP) 5-1

5.1 - Executive Summary 5-5

5.1.1 - Introduction 5-5

5.1.2 - Purpose of Study 5-5

5.1.3 - General Conclusions and Recommendations 5-5

5.2 - Planning Criteria 5-7

5.2.1 - Distribution System 5-7

5.2.2 - Substation 5-8

5.2.3 - Basis of Cost Estimates 5-8

5.3 - System Forecast 5-11

5.4 - Overhead Maintenance Program 5-26

5.5 - Capital Maintenance Project 5-27

5.6 - Substation Capacity Analysis 5-46

5.7 - Distribution System Analysis 5-47

5.8 - Total Cost Estimate 5-75
List of Table, Charts, and Images Page
Table 5.2.3-1 – Conductor Material Cost 5-8
Table 5.2.3-2 Pole Material Cost 5-8
Table 5.2.3-3 Transformer Material Cost 5-9
Table 5.2.3-4 Framing Units Material Cost 5-9
Table 5.2.3-5 Underground Material Cost 5-10
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost 5-10 Table 5.2.3-7 Underground Construction Labor and Fleet Cost 5-10 Banning Electric Utility Demand Forecast Table 5-12
Banning Electric Utility Non-Coincident System Peak Forecast Chart 5-13 Banning Electric Utility Coincident System Forecast Chart 5-14 Conceptual Banning Electric Utility Coincident System Forecast Chart 5-15 Banning Electric Utility MWH Purchases Chart 5-19
San Gorgonio Total kW Demand Chart 5-20
Midway Total kW Demand Chart 5-21
22nd Street Total kW Demand Chart 5-22
Stagecoach Total kW Demand Chart 5-23
Ivy Total kW Demand Chart 5-24
Sunset Total kW Demand Chart 5-25
Table 5.4-1 – Overhead Maintenance Program Costs 5-26
Table 5.5-1 – Capital Maintenance Project Costs 5-27
Table 5.6-1 – Substation Capacity Analysis 5-46
5-3
19046

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Image 5.7-1 – CIP Project 1 5-48
Image 5.7-2 – CIP Project 2 5-49
Image 5.7-3 – CIP Project 3 5-50
Image 5.7-4 – CIP Project 4 5-51
Image 5.7-5 – CIP Project 5 5-52
Image 5.7-6 – CIP Project 6 5-53
Image 5.7-7 – CIP Project 7 5-54
Image 5.7-8 – CIP Project 8 5-55
Image 5.7-9 – CIP Project 9 5-56
Image 5.7-10 – CIP Project 10 5-57
Image 5.7-11 – CIP Project 11 5-58
Image 5.7-12 – CIP Project 12 5-59
Image 5.7-13 – CIP Project 13 5-60
Image 5.7-14 – CIP Project 14 5-61
Image 5.7-15 – CIP Project 15 5-62
Image 5.7-16 – CIP Project 16 5-63
Image 5.7-17 – CIP Project 17 5-64
Image 5.7-18 – CIP Project 18 5-65
Image 5.7-19 – CIP Project 19 5-66
Image 5.7-20 – CIP Project 20 5-67
Image 5.7-21 – CIP Project 21 5-68
Image 5.7-22 – CIP Project 22 5-69
Image 5.7-23 – CIP Project 23 5-70
Image 5.7-24 – CIP Project 24 5-71
Image 5.7-25 – CIP Project 25 5-72
Image 5.7-26 – CIP Project 26 5-73
Image 5.7-27 – CIP Project 27 5-74
Table 5.8-1 – Total 5-Year CIP Cost Estimate 5-75
5-4
19147

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.1 - EXECUTIVE SUMMARY

5.1.1 - Introduction
The City of Banning owns the utility that provides electric service to Banning, California and the electric utility is maintained by Banning Electric Utility (BEU). Originally established in 1913 as a private utility, the City of Banning purchased the electric utility in 1922 and has been providing electric service to its residents since that time. Banning’s energy resource base includes portions of nuclear, geothermal, solar, landfill gas-to-energy, and hydro generating plants, that provide the majority of electricity required to meet the system peak demand.

Through an agreement with Southern California Edison Company (SCE), the BEU system utilizes SEC’s transmission system in bringing power from the California Independent System Operator (“CAISO”) controlled high voltage transmission grid to the BEU distribution system at the Banning Substation. BEU maintains three, 34.5kV sub-transmission circuits totaling approximately eighteen miles which feed six distribution substations.

These six distribution substations have approximately 27 circuits feeding 147 miles of overhead and underground distribution line with an operating voltage of 7.2/12.5 kV. An estimated 47% of the total distribution line is underground.

The City of Banning supports clean-energy and is committed to additional renewable energy resources to its already diverse portfolio. BEU has met and/or exceeded the renewable energy requirements of Compliance Period #1, Compliance Period #2, and Compliance Period #3 of the State’s Renewables Portfolio Standard (RPS) program. The Utility was 81 percent renewable in 2022, already exceeding the current State mandate of 60 percent by 2030.

BEU is a member of the Southern California Public Power Authority (SCPPA) enjoying the benefits of joint action through cost effective planning, construction, management, and operations of electrical energy resources.

5.1.2 - Purpose of Study
This 5-year Capital Improvement Plan (CIP) is a study prepared by Finley Engineering Company, Inc. (Finley) based on an analysis and review of the historical system growth and operation to determine projections of future growth, recommendations for capital improvements, and scheduled system maintenance that will insure the continued economical and reliable operation of the system over the ensuing 5-year period.

5.1.3 – General Conclusions and Recommendations
The 5-Year CIP includes projects and estimated costs for Overhead Maintenance, Capital Maintenance, and Distribution System Improvements.

The Overhead Maintenance program include the inspection of 3,900 poles and the replacement of 350 pole at a total estimated cost of $4,058,438.

Capital Maintenance includes 18 various projects such as underground conductor replacement, fiber extensions, substation breaker upgrades, fire mitigation, line hardening, line re-routes and/or relocation, recloser installations for sectionalizing, etc. The total estimated cost for these projects 5-5
19248

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
is $20,784,500. It is expected that BEU will receive $9,293,750 in cost in aid to construction (CIAC) bringing the total BEU funding cost to $11,490,750.

Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include 14 projects to switch load to adjacent lines to reduce single-phase line loading at a total estimated cost of $41,700, 2 projects for new line construction of 600’ totaling $336,400, 9 projects for singlephase to three-phase line rebuild of 10,107’ totaling $2,142,100, and 2 projects for three-phase line rebuild using larger conductor of 2,130’ totaling $285,500. The total estimated cost for distribution system improvements is $2,805,700.

The total estimated cost for the 5-Year CIP is $27,648,638 with an estimated $9,293,750 in CIAC reducing the BEU funding estimate to $18,354,888. For the BEU funding cost, 22% is for Overhead Maintenance, 63% is for Capital Maintenance, and 15% is for Distribution System improvements.
5-6
19349

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.2 – Planning Criteria

5.2.1 - Distribution System
The distribution projects contained in this 5-Year CIP are recommended based upon the following planning criteria.
a. With an assumed delivered voltage of 125 volts (1.041 per unit on a 120 volt base) during peak load conditions, the design minimum allowable voltage at the primary terminals of any distribution transformer shall be 118 volts (0.98 per unit on a 120 volt base). b. Voltage regulators and step transformers will be upgraded when projected peak loads exceed 85% of the device’s rating.
c. Sectionalizing devices will be upgraded when projected peak loads exceed 70% of the device’s continuous current rating.
d. Primary conductors on the 7.2/12.5 kV and below distribution system will be upgraded when projected peak loads exceed 60% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 60% of the conductor’s thermal rating
e. Primary conductors on the 34.5 kV sub-transmission system will be upgraded when projected peak loads exceed 90% of the conductor’s thermal rating and may be subject to upgrade before this time if anticipated load growth may potentially exceed 90% of the conductor’s thermal rating
f. Single-phase primary voltage lines will be limited to 35 amps maximum loading. g. The power factor at the delivery point under peak loading conditions is desired to be no less than 95%. The off-peak power factor should preferably be maintained between 95% lagging and 95% leading. This criterion is subject to the cost of the installation of capacitors, switches, and controls vs. the cost of kilowatt (kW) loss reduction.

5.2.1.1 - Distribution System Design Criteria
The following design criteria was considered when determining projects contained in this 5-year CIP.
a. Feeder current balance will be maintained at plus or minus 20% of the average per phase loading during peak conditions. This criterion may be relaxed in areas where it could impose unnecessary or premature costs.
b. Conductor sizes will be economically sized but may be modified to conform to BEU’s standard conductor sizes.
c. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any load voltage or high conductor loading. 5-7
19450

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
d. Load switching and backfeeding will be considered to defer unnecessary or premature costs to correct any high single-phase loading. For areas where there is no backfeed or load switch solution, additional conductors will be added to allow for phase balancing. e. Relocation of existing line sections will be considered where inaccessibility impedes the maintenance of line sections or jeopardizes the service or reliability of line sections.

5.2.2 – Substation
The substation projects contained in this 5-Year CIP are recommended based upon the following planning criteria.
a. Substation transformers will limited to 95% of the max kVA rating of the transformer. The following improvements will be considered in the event the load exceeds 95% of the max kVA rating:
a. Load switching to adjacent substations
b. Upgrade of existing transformer
c. Installation of an additional transformer in the existing substation d. Construction of a new substation

5.2.3 – Basis of Cost Estimates
The following tables for material and labor costs were used to determine total project costs. The costs were taken from actual prices provided by BEU as well as prices received by FEC from other sources.

Table 5.2.3-1 Conductor Material Cost
Conductor (price per foot)
OH Conductor UG Conductor
#2 Copper $1.31 1/0 AL, 15 kV $2.03
#2 ACSR $0.26 1/0 CU, 15 kV $10.98
#4 ACSR $0.15 1/0 CU, 35 kV $8.47
1/0 ACSR $0.30 4/0 CU $6.95
4/0 Copper $3.11 4/0 AL $4.97
4/0 ACSR $0.80 350 CU $7.53
336 ACSR $1.62 750 AL $13.38
Table 5.2.3-2 Pole Material Cost
Pole Price per unit Pole Price per unit
35' Douglas Fir, H2 $1,269.30 35’ Wood, Class 2 $1,067.38 40’ Wood, Class 2 $766.35
45' Douglas Fir, H2 $1,771.08 45’ Wood, Class 2 $953.80 50’ Wood, Class 2 $1,135.73
55' Douglas Fir, H2 $2,889.48 55’ Wood, Class 2 $918.72 60' Douglas Fir, H2 $2,945.89 60’ Wood, Class 2 $1,362.29 5-8
19551

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.2.3-3 Transformer Material Cost
Transformer Price per unit
10 kVA O.H. Transformer S-Type 7,200 $500.00
15 kVA 7,200, 120/240 DV S-Type $645.42
25 kVA 7,200, 120/240 DV S-Type $919.16
37 kVA 7,200, 120/240 DV S-Type $1,496.65
50 kVA 7,200 120/240 $3,992.05
75 kVA 3Ø 12,470/7,200 120/208 $6,023.22
300 kVA DV $8,583.61
750 kVA 3Ø 12,470/7,200 $14,626.30
1,000 kVA 3Ø 12,470/7,200 DV $10,809.48
2,500 kVA 3Ø 12,470/7,200 277/480 $34,539.92
25 kVA 1Ø 12,470/7,200 120/240 Pdmnt $3,685.34

37.5 kVA 1Ø 12,400/7,200 DV Pdmnt $1,988.01
75 kVA 1Ø 12,470/7,200 120/240 Pdmnt $7,110.42
300 kVA 3Ø 12,470/4,160 DV Pdmnt 208/120 $13,547.15
500 kVA 3Ø Pdmnt $10,442.65
1,500 kVA DV 3Ø Pdmnt 277/480 $31,037.04
Table 5.2.3-4 Framing Units Material Cost
Framing Unit Price per unit
A1.3P $75.32
A1.11P $493.46
A5.2G $286.41
A3.1 $78.74
A6.21 $1,080.29
G1.2 $317.41
G1.2 $1,318.96
A5.1 $195.12
A5.21 $888.35
(A4.1) $255.90
G1.3 $433.79
G1.3 $1,127.02
C1.11 $628.33
C1.81G $1,592.53
C1.11,A5.21 $1,516.68
C5.82G $3,472.80
C3.1 $208.96
C3.1,A5.1 $404.08
C3.1,A5.21 $1,097.31
C3.1, C5.1 $376.78
C5.1 $167.82
C5.1,A5.1 $362.94
C5.1,A5.21 $1,056.17
5-9
19652

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.2.3-5 Underground Material Cost
Material Price per unit
Light Duty Secondary Box $78.42
Light Duty Secondary Lid $83.43
4" PVC SCH 40 (per foot) $1.69
1/0 AL U/G (per foot) $4.75
Service Entrance Sleeve $0.45
Deadend Shoe Small $8.58
Power Solve (Pulling Lube) $58.98
Table 5.2.3-6 Overhead Construction Labor and Fleet Cost Units
(hr.)
Unit Cost
(per hr.)
Utility Bed P/U 1 ton (Foreman) (2 hrs. per connection) 4 $27.78 2 Person Lift (Bucket Truck) 55' (2 hrs. per connection) 2 $51.68 4 Person Crew 4 $466.73
3 Person Crew (2 hours per connection) 4 $352.02
2 Person Crew 2 $237.31
Electrical Engineering Supervisor (0.5 hrs. per connection) 1 $125.98 Electric Service Planning Supervisor (0.5 hrs. per connection) 1 $127.97 GIS Technician (1 hr. per connection) 2 $59.21
For overhead line, project cost estimates are based on an average of construction 1 mile of line per month with average span lengths at 150’.

Table 5.2.3-7 Underground Construction Labor and Fleet Cost Labor Price per hr.
4 Person Line Crew $466.73
Powerline Crew Superintendent $135.93
Fleet Price per hr.

Dump Truck $55.98
Utility Bed P/U 1 ton (Foreman) (3) $27.78
Digger Derrick $48.77
Wire Puller $24.98
Reel Trailer $24.98
Backhoe $23.95
For underground line, project estimates are based on an average construction of 1 month to trench, lay conduit, pull wire and terminate, and backfill 300’.

Engineering (10%) and contingency (5%) were also added for each cost estimate. 5-10
19753

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.3 – System Forecast
The 5-year CIP demand forecast was prepared to project the summer and winter kW demand per substation area as well as the total system demand for the City of Banning for the 2025-2030 CIP period. The historical non-coincident substation demands as well as the historical coincident system demands were provided by BEU and used as the basis for the forecast. BEU also provided insight into new load additions that are in some sort of application or planning process and were used in the conceptual forecast.

Additional factors that were considered when reviewing the historical peaks include temporary load switching between substations, construction of new substations with permanent load switching, and removal and/or replacement of existing substations.

Along with new load additions, considerations were also made for the addition of EV chargers at new subdivision locations.

This forecast will be used to run voltage drop and load flow analysis to determine system improvements required to reliably serve the City of Banning existing consumers and allow for future consumer growth.

It is projected that the BEU system will reach a non-coincident peak of 79,004 kW in the summer of 2030 and 59,385 kW in the winter of 2030. It is also projected that the BEU system will reach a coincident peak of 63,576 kW in the summer of 2030 and 53,737 kW in the winter of 2030.

A separate conceptual forecast was created to include new load additions that are in some state of application or planning process. It is projected that the BEU system will reach a conceptual non-coincident peak of 86,777 kW in the summer of 2030 and 76,938 kW in the winter of 2030.

As part of the historical review, MWH purchases were also reviewed and a forecast was determined. It is projected that the BEU system will have an annual coincident purchase of 192,127 MWH’s by 2030.

A graphical representation of the individual substation demand forecast as well as the total system coincident demand, non-coincident demand, conceptual non-coincident demand and MWH purchases is included following this page.
5-11
19854

BANNING ELECTRIC UTILTIY
2026-2045 ESMP SYSTEM FORECAST
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 San Gorgonio Total
S 16,425 17,079 16,472 9,131 4,958 16,500 16,830 17,167 17,510 17,860 18,217 18,582 18,953 19,332 19,719 20,113 20,516 20,926 21,345 21,771 22,207 22,651 23,104 23,566 24,037 24,518 2.0% W 15,022 12,746 11,267 7,193 3,739 15,000 15,300 15,606 15,918 16,236 16,561 16,892 17,230 17,575 17,926 18,285 18,651 19,024 19,404 19,792 20,188 20,592 21,004 21,424 21,852 22,289 2.0% Cannabis Cultivation 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 3,159 Yoshinoya 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 89 S 16,425 17,079 16,472 9,131 4,958 19,748 20,078 20,415 20,758 21,108 21,465 21,830 22,201 22,580 22,967 23,361 23,764 24,174 24,593 25,019 25,455 25,899 26,352 26,814 27,285 27,766 1.7% W 15,022 12,746 11,267 7,193 3,739 18,248 18,548 18,854 19,166 19,484 19,809 20,140 20,478 20,823 21,174 21,533 21,899 22,272 22,652 23,040 23,436 23,840 24,252 24,672 25,100 25,537 1.7% Midway Total
S 13,541 13,649 14,272 17,082 15,786 15,052 15,458 15,876 16,304 16,745 17,197 17,661 18,138 18,628 19,131 19,647 20,178 20,722 21,282 21,856 22,447 23,053 23,675 24,314 24,971 25,645 2.7% W 10,384 9,247 7,788 6,868 10,715 9,663 9,924 10,192 10,467 10,750 11,040 11,338 11,644 11,958 12,281 12,613 12,953 13,303 13,662 14,031 14,410 14,799 15,199 15,609 16,031 16,463 2.7% Airport
S 365 370 360 32 30 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% W 389 389 280 23 22 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.0% 22nd Street
S 10,233 10,319 9,736 10,585 11,240 10,670 10,787 10,906 11,026 11,147 11,270 11,394 11,519 11,646 11,774 11,904 12,034 12,167 12,301 12,436 12,573 12,711 12,851 12,992 13,135 13,280 1.1% W 8,140 6,529 6,105 6,567 8,018 8,210 8,300 8,392 8,484 8,577 8,672 8,767 8,863 8,961 9,059 9,159 9,260 9,362 9,465 9,569 9,674 9,781 9,888 9,997 10,107 10,218 1.1% Stagecoach
S 0 0 0 6,634 8,040 6,700 6,834 6,971 7,110 7,252 7,397 7,545 7,696 7,850 8,007 8,167 8,331 8,497 8,667 8,841 9,017 9,198 9,382 9,569 9,761 9,956 2.0% W 0 0 0 3,616 7,955 3,800 3,876 3,954 4,033 4,113 4,196 4,279 4,365 4,452 4,541 4,632 4,725 4,819 4,916 5,014 5,114 5,217 5,321 5,427 5,536 5,647 2.0% Ivy
S 0 0 5,308 7,206 8,333 5,400 5,508 5,618 5,731 5,845 5,962 6,081 6,203 6,327 6,453 6,583 6,714 6,849 6,985 7,125 7,268 7,413 7,561 7,713 7,867 8,024 2.0% W 0 0 4,493 4,890 6,235 4,500 4,590 4,682 4,775 4,871 4,968 5,068 5,169 5,272 5,378 5,485 5,595 5,707 5,821 5,938 6,056 6,178 6,301 6,427 6,556 6,687 2.0% Morongo Health Clinic 0 0 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 636 S 0 0 5,308 7,206 8,333 5,400 5,508 6,254 6,367 6,481 6,598 6,717 6,839 6,963 7,089 7,219 7,350 7,485 7,621 7,761 7,904 8,049 8,197 8,349 8,503 8,660 2.4% W 0 0 4,493 4,890 6,235 4,500 4,590 5,318 5,411 5,507 5,604 5,704 5,805 5,908 6,014 6,121 6,231 6,343 6,457 6,574 6,692 6,814 6,937 7,063 7,192 7,323 2.5% Sunset
S 8,140 8,099 9,586 11,441 14,821 10,439 10,857 11,291 11,742 12,212 12,701 13,209 13,737 14,286 14,858 15,452 16,070 16,713 17,382 18,077 18,800 19,552 20,334 21,147 21,993 22,873 4.0% W 6,716 5,803 5,037 8,299 11,443 6,319 6,572 6,835 7,108 7,392 7,688 7,996 8,315 8,648 8,994 9,354 9,728 10,117 10,522 10,942 11,380 11,835 12,309 12,801 13,313 13,846 4.0% Crestwood Communities 432 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 864 Vista Robles KB homes 0 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 1,512 S 8,140 8,099 9,586 11,441 14,821 10,871 13,233 13,667 14,118 14,588 15,077 15,585 16,113 16,662 17,234 17,828 18,446 19,089 19,758 20,453 21,176 21,928 22,710 23,523 24,369 25,249 4.3% W 6,716 5,803 5,037 8,299 11,443 6,751 8,948 9,211 9,484 9,768 10,064 10,372 10,691 11,024 11,370 11,730 12,104 12,493 12,898 13,318 13,756 14,211 14,685 15,177 15,689 16,222 4.5% Alola
S 2,929 2,370 1,646 372 0000000000000000000000 0.0%
W 2,377 708 782 336 0000000000000000000000 0.0%
Banning Electric Utility Non-Coincident System Peak Forecast S 51,632 51,885 57,380 62,482 63,207 68,441 71,898 74,088 75,683 77,322 79,004 80,732 82,507 84,330 86,202 88,126 90,103 92,134 94,221 96,367 98,571 100,837 103,167 105,562 108,024 110,556 2.4% W 43,029 35,422 35,752 37,792 48,126 51,172 54,186 55,919 57,045 58,200 59,385 60,600 61,847 63,127 64,440 65,788 67,172 68,592 70,050 71,546 73,083 74,661 76,281 77,945 79,654 81,410 2.3% Banning Electric Utility System Coincident Forecast
S 51,197 49,751 52,667 51,096 55,143 56,467 57,822 59,210 60,631 62,086 63,576 65,102 66,664 68,264 69,902 71,580 73,298 75,057 76,858 78,703 80,592 82,526 84,507 86,535 88,612 90,738 2.4% W 40,752 25,776 34,719 32,262 46,883 47,962 49,065 50,193 51,348 52,529 53,737 54,973 56,237 57,530 58,854 60,207 61,592 63,009 64,458 65,940 67,457 69,009 70,596 72,219 73,881 75,580 2.3% Conceptual Banning Electric Utility System Coincident Forecast S 51,197 49,751 52,667 51,096 55,143 56,467 58,962 61,201 69,810 76,184 86,777 100,472 109,135 120,377 129,082 137,336 145,321 153,347 157,527 161,751 166,019 167,953 169,934 171,962 174,039 176,165 5.9% W 40,752 25,776 34,719 32,262 46,883 47,962 50,205 52,185 60,527 66,627 76,938 90,343 98,708 109,643 118,034 125,963 133,615 141,299 145,127 148,988 152,884 154,436 156,023 157,646 159,308 161,007 6.2% Bridge-Morongo Logistics 0000 1,031 1,991 2,858 3,344 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 3,641 Sunset Crossroads 0 0 0 2,712 2,712 6,967 10,213 10,561 13,639 14,439 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 14,748 Rancho San Gorgonio 0 0 0 3,888 7,776 11,664 15,552 19,440 23,328 27,216 31,104 34,992 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 38,880 Mission Heights 000000 2,379 4,758 7,137 9,516 11,895 14,274 16,653 19,032 21,411 23,790 23,790 23,790 23,790 23,790 23,790 First Hathaway Logistics 0 0 0 0 0 0 471 471 471 471 471 471 471 471 471 471 471 471 471 471 471 Banning Commerce Center 0 0 0 0 0 0 438 438 438 438 438 438 438 438 438 438 438 438 438 438 438 WEKA 007777777777777777777
Charles St. CDRE 0 0 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 KCB Towers 0 0 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 20 Pallet Yard 007777777777777777777
First Lincoln Logistics 0 0 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 186 Brown Strauss 0 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 390 Wyndam Micro Hotel 0 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 750 DR Horton 0 0 588 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 1,175 Atwell Large Retail 0 0 0 0 0 0 880 880 880 880 880 880 880 880 880 880 880 880 880 880 880 2025-2045
Annual
Growth Rate
Historical Forecast
Peak kW Demand
5-12
19955
.00

80.0060.0040.0020.00
120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY NON-COINCIDENT SYSTEM PEAK FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
5-13
20056
.00

90.0080.0070.0060.0050.0040.0030.0020.0010.00
100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.3% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.4% ANNUAL GROWTH
RATE
5-14
20157
.00

80.0060.0040.0020.00
200.00180.00160.00140.00120.00100.00
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MW (x1,000)
YEAR

CONCEPTUAL BANNING ELECTRIC UTILITY COINCIDENT SYSTEM FORECAST

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

6.2% ANNUAL GROWTH
RATE

SUMMER-FORECAST

5.9% ANNUAL GROWTH
RATE
5-15
20258

BANNING ELECTRIC UTILITY
2026-2045 ESMP NON-COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 11,577 21.27 12,259 22.52 12,651 23.24 12,906 23.71 13,167 24.19 13,435 24.68 13,710 25.19 Feb 10,470 21.33 11,086 22.58 11,441 23.31 11,671 23.78 11,907 24.26 12,150 24.75 12,399 25.26 Mar 10,870 20.69 11,511 21.91 11,879 22.61 12,118 23.07 12,363 23.54 12,615 24.01 12,873 24.51 Apr 13,733 32.53 14,427 34.18 14,867 35.22 15,187 35.98 15,515 36.76 15,853 37.56 16,200 38.38 May 15,631 37.92 16,420 39.84 16,920 41.05 17,285 41.94 17,659 42.85 18,043 43.78 18,438 44.74 Jun 18,497 56.73 19,432 59.59 20,023 61.41 20,455 62.73 20,897 64.09 21,352 65.48 21,819 66.92 Jul 25,788 65.86 27,090 69.19 27,915 71.29 28,517 72.83 29,134 74.40 29,768 76.02 30,419 77.69 Aug 26,719 68.44 28,069 71.90 28,923 74.09 29,546 75.68 30,186 77.32 30,843 79.00 31,517 80.73 Sep 21,335 64.10 22,413 67.34 23,096 69.39 23,593 70.88 24,104 72.42 24,628 73.99 25,167 75.61 Oct 19,525 51.17 20,675 54.19 21,336 55.92 21,766 57.05 22,206 58.20 22,658 59.38 23,122 60.60 Nov 10,787 21.08 11,423 22.32 11,788 23.04 12,025 23.50 12,269 23.98 12,518 24.46 12,775 24.97 Dec 12,073 22.02 12,784 23.31 13,193 24.06 13,458 24.54 13,731 25.04 14,010 25.55 14,297 26.07 TOTAL: 197,005 207,588 214,032 218,526 223,138 227,873 232,734 Summer Peak (MW) 68.44 71.90 74.09 75.68 77.32 79.00 80.73 Winter Peak (MW) 51.17 54.19 55.92 57.05 58.20 59.38 60.60 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 13,992 25.71 14,282 26.24 14,579 26.79 14,884 27.35 15,197 27.92 15,518 28.51 15,848 29.12 Feb 12,654 25.78 12,916 26.31 13,184 26.86 13,460 27.42 13,743 28.00 14,034 28.59 14,332 29.20 Mar 13,138 25.01 13,410 25.53 13,689 26.06 13,975 26.60 14,269 27.16 14,571 27.74 14,880 28.33 Apr 16,556 39.22 16,922 40.09 17,297 40.98 17,683 41.89 18,080 42.83 18,488 43.80 18,907 44.79 May 18,843 45.72 19,259 46.73 19,687 47.77 20,126 48.83 20,578 49.93 21,042 51.05 21,518 52.21 Jun 22,299 68.39 22,791 69.90 23,297 71.45 23,817 73.04 24,352 74.68 24,901 76.37 25,465 78.10 Jul 31,087 79.39 31,774 81.15 32,480 82.95 33,205 84.80 33,950 86.70 34,715 88.66 35,501 90.67 Aug 32,210 82.51 32,922 84.33 33,653 86.20 34,404 88.13 35,176 90.10 35,969 92.13 36,783 94.22 Sep 25,720 77.27 26,288 78.98 26,872 80.74 27,472 82.54 28,088 84.39 28,721 86.29 29,372 88.25 Oct 23,598 61.85 24,086 63.13 24,587 64.44 25,102 65.79 25,630 67.17 26,171 68.59 26,728 70.05 Nov 13,038 25.48 13,307 26.01 13,584 26.55 13,868 27.10 14,160 27.67 14,459 28.26 14,767 28.86 Dec 14,591 26.61 14,893 27.16 15,203 27.73 15,521 28.31 15,847 28.90 16,182 29.51 16,526 30.14 TOTAL: 237,725 242,850 248,113 253,518 259,069 264,770 270,627 Summer Peak (MW) 82.51 84.33 86.20 88.13 90.10 92.13 94.22 Winter Peak (MW) 61.85 63.13 64.44 65.79 67.17 68.59 70.05 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 16,187 29.74 16,534 30.38 16,891 31.03 17,258 31.71 17,634 32.40 18,021 33.11 18,418 33.84 Feb 14,638 29.82 14,953 30.46 15,275 31.12 15,607 31.79 15,947 32.49 16,297 33.20 16,656 33.93 Mar 15,198 28.93 15,525 29.55 15,860 30.19 16,204 30.85 16,558 31.52 16,921 32.21 17,294 32.92 Apr 19,337 45.81 19,779 46.86 20,234 47.93 20,702 49.04 21,182 50.18 21,676 51.35 22,184 52.55 May 22,008 53.40 22,512 54.62 23,029 55.88 23,561 57.17 24,108 58.49 24,671 59.86 25,249 61.26 Jun 26,044 79.88 26,640 81.70 27,253 83.58 27,882 85.51 28,530 87.50 29,195 89.54 29,879 91.64 Jul 36,310 92.73 37,140 94.85 37,994 97.03 38,872 99.27 39,774 101.58 40,702 103.95 41,656 106.38 Aug 37,621 96.37 38,482 98.57 39,366 100.84 40,276 103.17 41,211 105.56 42,172 108.02 43,160 110.56 Sep 30,041 90.26 30,728 92.32 31,434 94.44 32,161 96.63 32,907 98.87 33,675 101.17 34,464 103.55 Oct 27,299 71.55 27,885 73.08 28,487 74.66 29,105 76.28 29,740 77.95 30,392 79.65 31,062 81.41 Nov 15,082 29.47 15,406 30.11 15,739 30.76 16,080 31.43 16,431 32.11 16,791 32.82 17,161 33.54 Dec 16,879 30.78 17,242 31.44 17,614 32.12 17,996 32.82 18,389 33.54 18,792 34.27 19,206 35.03 TOTAL: 276,644 282,826 289,178 295,705 302,412 309,305 316,390 Summer Peak (MW) 96.37 98.57 100.84 103.17 105.56 108.02 110.56 Winter Peak (MW) 71.55 73.08 74.66 76.28 77.95 79.65 81.41 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
5-16
20359

BANNING ELECTRIC UTILITY
2026-2045 ESMP COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,100 20.39 11,356 20.86 11,617 21.34 11,884 21.83 12,157 22.34 12,437 22.85 Feb 9,813 19.99 10,038 20.45 10,269 20.92 10,506 21.40 10,747 21.89 10,994 22.40 11,247 22.91 Mar 10,188 19.40 10,423 19.84 10,662 20.30 10,908 20.76 11,158 21.24 11,415 21.73 11,678 22.23 Apr 11,331 26.84 11,603 27.49 11,881 28.15 12,166 28.82 12,458 29.51 12,757 30.22 13,063 30.95 May 12,896 31.29 13,205 32.04 13,522 32.81 13,847 33.60 14,179 34.40 14,519 35.23 14,868 36.07 Jun 15,261 46.80 15,627 47.93 16,002 49.08 16,386 50.25 16,780 51.46 17,182 52.70 17,595 53.96 Jul 21,276 54.34 21,787 55.64 22,309 56.98 22,845 58.34 23,393 59.74 23,955 61.18 24,529 62.65 Aug 22,044 56.47 22,573 57.82 23,115 59.21 23,670 60.63 24,238 62.09 24,820 63.58 25,415 65.10 Sep 17,603 52.89 18,025 54.16 18,458 55.45 18,901 56.79 19,354 58.15 19,819 59.54 20,294 60.97 Oct 18,300 47.96 18,721 49.06 19,151 50.19 19,592 51.35 20,042 52.53 20,503 53.74 20,975 54.97 Nov 10,110 19.76 10,343 20.21 10,581 20.68 10,824 21.15 11,073 21.64 11,328 22.14 11,588 22.65 Dec 11,315 20.64 11,575 21.11 11,842 21.60 12,114 22.09 12,393 22.60 12,678 23.12 12,969 23.65 TOTAL: 170,987 175,020 179,149 183,374 187,700 192,127 196,659 Summer Peak (MW) 56.47 57.82 59.21 60.63 62.09 63.58 65.10 Winter Peak (MW) 47.96 49.06 50.19 51.35 52.53 53.74 54.97 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 12,723 23.38 13,016 23.91 13,315 24.46 13,621 25.03 13,935 25.60 14,255 26.19 14,583 26.79 Feb 11,506 23.44 11,771 23.98 12,041 24.53 12,318 25.09 12,602 25.67 12,891 26.26 13,188 26.86 Mar 11,946 22.74 12,221 23.26 12,502 23.80 12,790 24.35 13,084 24.91 13,385 25.48 13,693 26.07 Apr 13,377 31.69 13,698 32.45 14,027 33.23 14,363 34.03 14,708 34.84 15,061 35.68 15,422 36.54 May 15,225 36.94 15,590 37.83 15,964 38.73 16,347 39.66 16,740 40.62 17,142 41.59 17,553 42.59 Jun 18,017 55.26 18,449 56.58 18,892 57.94 19,346 59.33 19,810 60.75 20,285 62.21 20,772 63.71 Jul 25,118 64.15 25,721 65.69 26,338 67.27 26,970 68.88 27,618 70.53 28,281 72.23 28,959 73.96 Aug 26,025 66.66 26,650 68.26 27,289 69.90 27,944 71.58 28,615 73.30 29,302 75.06 30,005 76.86 Sep 20,781 62.44 21,280 63.94 21,791 65.47 22,314 67.04 22,849 68.65 23,398 70.30 23,959 71.98 Oct 21,457 56.24 21,951 57.53 22,456 58.85 22,972 60.21 23,501 61.59 24,041 63.01 24,594 64.46 Nov 11,855 23.17 12,128 23.70 12,406 24.25 12,692 24.80 12,984 25.37 13,282 25.96 13,588 26.55 Dec 13,268 24.20 13,573 24.75 13,885 25.32 14,204 25.90 14,531 26.50 14,865 27.11 15,207 27.73 TOTAL: 201,298 206,047 210,907 215,882 220,975 226,188 231,523 Summer Peak (MW) 66.66 68.26 69.90 71.58 73.30 75.06 76.86 Winter Peak (MW) 56.24 57.53 58.85 60.21 61.59 63.01 64.46 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 14,918 27.41 15,261 28.04 15,612 28.68 15,971 29.34 16,339 30.02 16,715 30.71 17,099 31.42 Feb 13,491 27.48 13,801 28.11 14,119 28.76 14,444 29.42 14,776 30.10 15,116 30.79 15,463 31.50 Mar 14,007 26.67 14,330 27.28 14,659 27.91 14,996 28.55 15,341 29.20 15,694 29.88 16,055 30.56 Apr 15,793 37.41 16,172 38.31 16,560 39.23 16,957 40.17 17,364 41.14 17,781 42.12 18,208 43.13 May 17,974 43.61 18,406 44.66 18,847 45.73 19,300 46.83 19,763 47.95 20,237 49.10 20,723 50.28 Jun 21,271 65.23 21,781 66.80 22,304 68.40 22,839 70.04 23,387 71.73 23,949 73.45 24,523 75.21 Jul 29,654 75.73 30,366 77.55 31,095 79.41 31,841 81.32 32,605 83.27 33,388 85.27 34,189 87.32 Aug 30,725 78.70 31,462 80.59 32,218 82.53 32,991 84.51 33,783 86.53 34,593 88.61 35,424 90.74 Sep 24,534 73.71 25,123 75.48 25,726 77.29 26,344 79.15 26,976 81.05 27,623 82.99 28,286 84.98 Oct 25,160 65.94 25,738 67.46 26,330 69.01 26,936 70.60 27,555 72.22 28,189 73.88 28,838 75.58 Nov 13,900 27.17 14,220 27.79 14,547 28.43 14,882 29.08 15,224 29.75 15,574 30.44 15,932 31.14 Dec 15,557 28.37 15,915 29.02 16,281 29.69 16,655 30.37 17,038 31.07 17,430 31.79 17,831 32.52 TOTAL: 236,985 242,576 248,298 254,156 260,152 266,289 272,571 Summer Peak (MW) 78.70 80.59 82.53 84.51 86.53 88.61 90.74 Winter Peak (MW) 65.94 67.46 69.01 70.60 72.22 73.88 75.58 Projected Load Data 2039-2045
Projected Load Data 2032-2038
2039 2040 2041 2042 2043 2044 2045
Projected Load Data 2025 - 2031
2032 2033 2034 2035 2036 2037 2038
2025 2026 2027 2028 2029 2030 2031
5-17
20460

BANNING ELECTRIC UTILITY
2026-2045 ESMP CONCEPTUAL COINCIDENT SYSTEM FORECAST
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 10,851 19.94 11,358 20.87 11,806 21.69 13,693 25.16 15,074 27.69 17,406 31.98 20,439 37.55 Feb 9,813 19.99 10,272 20.92 10,677 21.75 12,384 25.23 13,632 27.77 15,741 32.07 18,484 37.65 Mar 10,188 19.40 10,665 20.30 11,085 21.10 12,857 24.48 14,153 26.94 16,344 31.11 19,191 36.53 Apr 11,331 26.84 11,831 28.03 12,281 29.09 14,008 33.19 15,287 36.22 17,413 41.25 20,161 47.76 May 12,896 31.29 13,466 32.67 13,977 33.91 15,943 38.68 17,399 42.22 19,818 48.08 22,946 55.67 Jun 15,261 46.80 15,935 48.87 16,540 50.73 18,867 57.86 20,590 63.15 23,453 71.93 27,154 83.28 Jul 21,276 54.34 22,216 56.74 23,060 58.89 26,303 67.18 28,705 73.31 32,696 83.50 37,856 96.68 Aug 22,044 56.47 23,018 58.96 23,892 61.20 27,253 69.81 29,742 76.18 33,877 86.78 39,223 100.47 Sep 17,603 52.89 18,380 55.22 19,078 57.32 21,762 65.38 23,749 71.35 27,051 81.27 31,320 94.10 Oct 18,300 47.96 19,156 50.20 19,911 52.18 23,094 60.53 25,421 66.63 29,356 76.94 34,470 90.34 Nov 10,110 19.76 10,583 20.68 11,001 21.50 12,759 24.94 14,045 27.45 16,219 31.70 19,044 37.22 Dec 11,315 20.64 11,844 21.60 12,312 22.45 14,280 26.04 15,719 28.67 18,151 33.10 21,314 38.87 TOTAL: 170,987 178,725 185,621 213,204 233,515 267,525 311,603 Summer Peak (MW) 56.47 58.96 61.20 69.81 76.18 86.78 100.47 Winter Peak (MW) 47.96 50.20 52.18 60.53 66.63 76.94 90.34 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 22,332 41.03 24,806 45.58 26,704 49.06 28,498 52.36 30,229 55.54 31,967 58.73 32,833 60.32 Feb 20,195 41.14 22,433 45.70 24,149 49.19 25,772 52.50 27,337 55.69 28,909 58.89 29,692 60.49 Mar 20,968 39.92 23,291 44.34 25,073 47.73 26,758 50.94 28,383 54.03 30,016 57.14 30,829 58.69 Apr 21,899 51.88 24,155 57.22 25,902 61.36 27,558 65.29 29,160 69.08 30,771 72.90 31,610 74.88 May 24,924 60.47 27,492 66.70 29,480 71.53 31,365 76.10 33,188 80.53 35,021 84.97 35,976 87.29 Jun 29,495 90.46 32,534 99.78 34,886 106.99 37,117 113.83 39,275 120.45 41,444 127.10 42,574 130.57 Jul 41,121 105.02 45,356 115.84 48,637 124.21 51,746 132.15 54,755 139.84 57,779 147.56 59,354 151.58 Aug 42,606 109.14 46,994 120.38 50,393 129.08 53,615 137.34 56,732 145.32 59,866 153.35 61,498 157.53 Sep 34,021 102.21 37,526 112.74 40,239 120.90 42,812 128.63 45,301 136.11 47,803 143.62 49,107 147.54 Oct 37,662 98.71 41,835 109.64 45,036 118.03 48,061 125.96 50,981 133.62 53,913 141.30 55,373 145.13 Nov 20,808 40.66 23,113 45.17 24,882 48.63 26,553 51.89 28,166 55.05 29,786 58.21 30,593 59.79 Dec 23,287 42.47 25,867 47.17 27,847 50.78 29,718 54.20 31,523 57.49 33,336 60.79 34,239 62.44 TOTAL: 339,319 375,401 403,228 429,573 455,032 480,611 493,678 Summer Peak (MW) 109.14 120.38 129.08 137.34 145.32 153.35 157.53 Winter Peak (MW) 98.71 109.64 118.03 125.96 133.62 141.30 145.13 Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Total Load
for Month
(MWh)
Peak
MW
Jan 33,707 61.93 34,588 63.55 34,939 64.19 35,298 64.85 35,666 65.53 36,042 66.22 36,426 66.93 Feb 30,483 62.10 31,280 63.72 31,597 64.37 31,922 65.03 32,254 65.70 32,594 66.40 32,941 67.10 Mar 31,649 60.25 32,477 61.82 32,806 62.45 33,143 63.09 33,488 63.75 33,841 64.42 34,202 65.11 Apr 32,457 76.89 33,314 78.92 33,702 79.84 34,099 80.78 34,506 81.75 34,923 82.73 35,350 83.74 May 36,941 89.63 37,915 91.99 38,357 93.07 38,810 94.16 39,273 95.29 39,747 96.44 40,233 97.62 Jun 43,716 134.07 44,869 137.61 45,392 139.21 45,927 140.85 46,475 142.53 47,037 144.25 47,611 146.02 Jul 60,946 155.65 62,554 159.76 63,283 161.62 64,029 163.52 64,793 165.47 65,575 167.47 66,377 169.52 Aug 63,146 161.75 64,813 166.02 65,568 167.95 66,341 169.93 67,133 171.96 67,943 174.04 68,774 176.17 Sep 50,423 151.49 51,754 155.49 52,357 157.30 52,974 159.16 53,606 161.06 54,254 163.00 54,917 164.99 Oct 56,847 148.99 58,333 152.88 58,925 154.44 59,531 156.02 60,150 157.65 60,784 159.31 61,432 161.01 Nov 31,407 61.38 32,228 62.98 32,555 63.62 32,890 64.28 33,232 64.95 33,582 65.63 33,941 66.33 Dec 35,150 64.10 36,069 65.78 36,435 66.45 36,809 67.13 37,192 67.83 37,584 68.54 37,985 69.27 TOTAL: 506,871 520,193 525,915 531,773 537,769 543,906 550,188 Summer Peak (MW) 161.75 166.02 167.95 169.93 171.96 174.04 176.17 Winter Peak (MW) 148.99 152.88 154.44 156.02 157.65 159.31 161.01 2044 2045
Projected Load Data 2039-2045
2039 2040 2041 2042 2043
2038
Projected Load Data 2032-2038
2032 2033 2034 2035 2036 2037
Projected Load Data 2025 - 2031
2025 2026 2027 2028 2029 2030 2031
5-18
20561
0 50
300250200150100
'19 '20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 MWH (x1,000)
YEAR

BANNING ELECTRIC UTILTIY MWH PURCHASES

HISTORICAL

FORECAST

2.4% ANNUAL GROWTH
RATE
5-19
20662
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SAN GORGONIO TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.7% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.7% ANNUAL GROWTH
RATE
5-20
20763
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
MIDWAY TOTAL kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

SUMMER-FORECAST

2.7% ANNUAL GROWTH
RATE

WINTER-FORECAST

2.7% ANNUAL GROWTH
RATE
5-21
20864
0 8,0006,0004,0002,000
14,00012,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
22ND STREET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

1.1% ANNUAL GROWTH
RATE

SUMMER-FORECAST

1.1% ANNUAL GROWTH
RATE
5-22
20965
0 8,0006,0004,0002,000
12,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
STAGECOACH kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
5-23
21066
0 9,0008,0007,0006,0005,0004,0003,0002,0001,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
IVY kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

2.0% ANNUAL GROWTH
RATE

SUMMER-FORECAST

2.0% ANNUAL GROWTH
RATE
5-24
21167
0 5,000
30,00025,00020,00015,00010,000
'20 '21 '22 '23 '24 '25 '26 '27 '28 '29 '30 '31 '32 '33 '34 '35 '36 '37 '38 '39 '40 '41 '42 '43 '44 '45 kW
YEAR
SUNSET kW DEMAND

SUMMER-HISTORICAL

WINTER-HISTORICAL

WINTER-FORECAST

4.5% ANNUAL GROWTH
RATE

SUMMER-FORECAST

4.3% ANNUAL GROWTH
RATE
5-25
21268

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.4 – Overhead Maintenance Program
The Overhead Maintenance Program include the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect 15 poles per week for the years 2026 thru 2030. This totals to 780 poles inspected per year and 3,900 poles inspected for the duration of the 5-Year CIP. An estimated cost of $270 per pole inspection was used and a 3% inflation to this cost was assumed per year starting in 2027. The total estimated cost for pole inspections for the 5-Year CIP is $1,151,647.

It is projected that BEU will replace 50 poles per year for the years 2026 thru 2028 and 100 poles per year for the years 2029 and 2030. This totals to 350 poles replaced for the duration of the 5- Year CIP. An estimated cost of $7,520 per pole replacement was used and a 3% inflation to this cost was assumed per year starting in 2027. The total estimated cost for pole replacements for the 5-Year CIP is $2,906,791.

The total estimated cost for the Overhead Maintenance Program for the 5-year CIP is $4,058,438.

The table below shows a breakdown of the Overhead Maintenance Program.

Table 5.4-1 – Overhead Maintenance Program Costs
2026 2027 2028 2029 2030 Total
Number of Poles
Inspected 780 780 780 780 780 3,900
Cost per
Inspection 278 286 295 304 313 -
Total Cost of
Inspection $216,918 $223,426 $230,128 $237,032 $244,143 $1,151,647 Number of Poles
Replaced 50 50 50 100 100 350
Cost per
Replacement $7,746 $7,978 $8,217 $8,422 $8,675 -
Total Cost of
Replacement $387,280 $398,898 $410,865 $842,240 $867,507 $2,906,791 Total Overhead
Maintenance
Program
$604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 5-26
21369

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.5 – Capital Maintenance Projects
BEU has identified 18 Capital Maintenance projects to include in the 5-year CIP. The total estimated cost for these projects is $20,784,500. It is projected that BEU will receive $9,293,750 in contributions in aid to these projects bringing the total BEU funding cost to $11,490,750.

The following tables list the Capital Maintenance projects that have been identified for inclusion to the 5-year CIP.

Table 5.5-1 – Capital Maintenance Project Costs
Project Description Year Total Cost CIAC
BEU
Funding
Cost
Underground Conversion Livingston to
Hargrave (Backbone/Fiber loop at
Ramsey/Livingston/Alola)
2027-
2028 $149,500 $0 $149,500
Underground Conductor Replacement
Barbour St E/O Hathaway 2027 $275,000 $0 $275,000
Underground Conductor Replacement at
Mockingbird Lane and Hillside Dr 2027 $750,000 $0 $750,000 Underground Conductor Replacement at
Westward Ave from 4th St to 8th St 2027 $625,000 $0 $625,000 Fiber Extension to Stagecoach
Substation (UG and OH) 2027 $285,000 $0 $285,000
Midway Substation Upgrades (breaker
replacement and SCADA-ready
upgrades and future full replacement)
2027-
2030 $6,125,000 $0 $6,125,000

34.5 kV/12.47 kV (Cir 77)/fiber UG and
OH Extension to Sunset Ave 2029 $2,000,0001 $1,200,000 $800,000 SoCalGas Reimbursement for Feeder
Circuits to Cottonwood Ave 2027 TBD 100% $0
1 Up to 60% contribution from WKJ Development
5-27
21470

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.5-1 – Capital Maintenance Project Costs (continued) Project Description Year Total Cost CIAC
BEU
Funding
Cost
Underground Conductor Replacement
at Vista Serena Ave 2029 $350,000 $175,0002 $175,000
Fire Mitigation Tier 2/3 High Threat Area
(Various)
2026-
2028 $450,000 $0 $450,000
Mias Canyon Line Hardening 2027 $2,100,000 $2,100,0003 $0

34.5 kV/12.47 kV/fiber Underground
Circuits Hathaway St from Williams St
to Hoffer St
2029-
2030 $2,000,000 $2,000,0004 $0

34.5 kV/12.47 kV/fiber Underground
Circuits Lincoln St to John St
2027,
2029 $150,000 $0 $150,000
Install Two (2) Engineered base-plate
pole at Sunset and Lincoln
2028-
2029 $850,000 $0 $850,000
Install Reclosers on 34.5 kV and 12.47
kV system 2028 $250,000 $0 $250,000
Robertson's Ready Mix Circuit Re-route 2026-
2028 $425,000 $318,7505 $106,250
Sun Lakes Blvd Extension - Electric
Relocation
2026-
2028 $3,500,000 $3,500,0006 $0
2 Up to 50% contribution from Vista Serena Developer
3 100% grant funded
4 100% funded from Sansone Group and First Hathaway Industrial 5 Up to 75% contribution from Robertson’s Ready Mix
6 100% Public Works funded
5-28
21571

CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Table 5.5-1 – Capital Maintenance Project Costs (continued) Project Description Year Total Cost CIAC
BEU
Funding
Cost
SCE Upfront Capital Costs 2028 $500,000 $0 $500,000
$20,784,500 $9,293,750 $11,490,750
The following pages contain the CIP worksheets as provided by BEU. 5-29
21672

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$149,500 $9,500 $140,000
$149,500 $9,500 $140,000 $0 $0 $0 $0
Engineering
Project Title:

Complete distribution circuit ties between San Gorgonio Substation and Stagecoach Substation that will provide electric distribution to the area that had been previously served by the decommissioned Alola Substation. This project will include short distance line extensions, installation of PME switches, and fiber optic cable installation.

Estimated Completion Date:

Underground Conversion Livingston to Hargrave (Backbone/Fiber loop at Ramsey/Livingston/Alola ) 12/1/2027
Project Description:

Provides added redundancy and resiliency to distribution service in the northeast section of BEU's service territory.

Project Status: Photo/Exhibit/Vicinity Map
Currently in design; construction phase is tentatively scheduled to commence construction during FY 26/27 and will conclude in FY 27/28.

Budget Distribution Est. Amount
$9,500
$0
$0
$5,000
$135,000
$149,500
Electric Revenue $149,500
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $149,500
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-30
73 217

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$275,000 $275,000
$275,000 $275,000 $0 $0 $0 $0 $0
Engineering
Brandon Robinson, Electric Engineering Supervisor
Project Description:

Complete 12.47kV conversion for four service at 700 S. Hathaway St. Decommission Airport Substation.

Funding Plan:

Division: Contacts:
$0
$0
$275,000
Department:

Electric Fred Lyn, Deputy Electric Utility Director
Total
Project Title: Estimated Completion Date:

Funding Source Total
$275,000
This project will conclude the 12kV Conversion project that has taken BEU nearly 50 years to complete. This will provide stable service reliability in the area.

Est. Amount
Photo/Exhibit/Vicinity Map Project Status:

Currently in design; construction phase is tentatively scheduled to commence construction during FY 26/27.

Underground Conversion Barbour St (12kV Conversion at 700 S. Hathaway) 12/1/2026 Budget Distribution
Electric Revenue
$275,000
$20,000
$0
$0
$5,000
$250,000
5-31
74 218

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$750,000 $750,000
$750,000 $750,000 $0 $0 $0 $0 $0
Engineering
Project Title:

Complete reconductoring on Hillside Dr and Mockingbird Ln.

Estimated Completion Date:

Underground Conductor Replacement - Mockingbird & Hillside 12/1/2026 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
The initial phase of this project was completed in 2023 due to the occurrence of a fault on an unjacketed primary distribution conductor within the project area; the final phase of construction phase is tentatively scheduled to commence during FY 26/27.

Budget Distribution Est. Amount
$55,000
$0
$0
$18,000
$677,000
$750,000
Electric Revenue $750,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $750,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-32
75 219

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$625,000 $625,000
$625,000 $625,000 $0 $0 $0 $0 $0
Engineering
Project Title:

Complete reconductoring on between Westward Ave and Barbour St, from 4th St to 8th St.

Estimated Completion Date:

Underground Conductor Replacement - Westward Ave to Barbour St, 4th St to 8th St 6/1/2026 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
Some preliminary reconductoring occurred during a 2022 fault event involving unjacketed primary distribution conductor within the project area; construction of all improvements is tentatively scheduled to commence during FY 26/27.

Budget Distribution Est. Amount
$25,000
$0
$0
$10,000
$590,000
$625,000
Electric Revenue $625,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $625,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-33
76 220

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$285,000 $285,000
$0
$285,000 $285,000 $0 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $285,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $285,000
CIAC $0
Funding Source Total
This project will help push BEU toward completion of fiber optic hard line connectivity all six substations for SCADA monitoring and control.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
In 2022, BEU completed a line extension on Hargrave Street from the site of the decommissioned Alola Substation to the newly built Stagecoach Substation in order to energize the asset and provide service to the northeast portion of BEU's service area.

The design for this pole line extension included provisions for a future utility fiber optic line attachment to support SCADA communication. BEU anticipates construction to commence during FY 26/27, but may be able to be delayed and encumbered into future fiscal year budgets if needed.

Budget Distribution Est. Amount
$15,000
$0
$0
$5,000
$265,000
$285,000
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits thru easement within Banning Airport property from Lincoln St to John St.

Estimated Completion Date:

Fiber Extension to Stagecoach 12/30/2027
Project Description:
5-34
77 221

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$125,000 $75,000 $50,000
$125,000 $75,000 $50,000 $0 $0 $0 $0
Engineering
Project Title:

Install SCADA RTU and other equipment to make Midway Substation SCADA ready. Replace distribution with spare breakers as needed. This project will also address potential full substation upgrade if direction is to utilize the existing property.

Estimated Completion Date:

Midway Substation Upgrades (breaker replacement and SCADA upgrades) 5/30/2028 Project Description:

Midway is BEU's oldest Substation, built in 1972. Most of the equipment, including the transformers and distribution breakers are original and nearing the end of useful life. The SCADA upgrades will allow remote visibility at the substation, while as-needed breaker replacement will allow the substation to continue operating as intended. The eventual replacement of all equipment at the substation will help conclude modernization of all BEU's substation assets.

Project Status: Photo/Exhibit/Vicinity Map
BEU has began vetting equipment that will be utilized to make Midway Substation SCADA-ready. Construction of this phase is tentatively scheduled to commence during FY 26/27. All other improvements we be evaluated later in the initial 5-yr CIP period.

Budget Distribution Est. Amount
$5,000
$0
$0
$2,500
$117,500
$125,000
Electric Revenue $125,000
$0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $125,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-35
78 222

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$800,000 $800,000
$1,200,000 $1,200,000
$2,000,000 $0 $0 $2,000,000 $0 $0 $0
Engineering
Project Title:

Extend electric sub-transmission and distribution from Mountain Ave to Sunset Ave.

Estimated Completion Date:

34.5kV/12.47kV (Cir 77)/fiber UG and OH Extension to Sunset Ave 6/30/2029 Project Description:

Circuit #77, which originates from Sunset Substation, is terminated in a switch cabinet on Mountain Ave. This circuit was designed to provide distribution services to newer developments along Sunset Ave north of Wilson St. Completing this line extension allows BEU to fulfill this need, while also seeking monetary contributions from these developments thru line extension agreements.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed a preliminary design of the 12.47kV distribution extension thru the area. Design for the 34.5kV and fiber extension still needs to be completed.

Environmental, survey, and possible ROW acquisition will be required for this project.

Construction is tentatively scheduled to commence during FY 28/29, or as soon as advance on construction is received for from developers in the area that will be served with this line extension.

Budget Distribution Est. Amount
$115,000
$50,000
$75,000
$45,000
$1,715,000
$2,000,000
Electric Revenue $800,000
CIAC (WJK Development) $1,200,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $2,000,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-36
79 223

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$175,000 $175,000
$175,000 $175,000
$350,000 $175,000 $0 $175,000 $0 $0 $0
Engineering
Project Title:

Complete reconductoring of unjacketed cable in the Vista Serena development in conjunction with an ongoing development-driven project to complete buildout of the complex.

Estimated Completion Date:

Underground Conductor Replacement at Vista Serena 6/30/2029 Project Description:

This project will address replacement of antiquated unjacketed cable in BEU's system. The unjacketed cable has become obsolete and is prone to greater percentage of fault occurrence, which leads to longer customer outages.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed minor reconductoring within Vista Serena that had come as a result of outages created by cable fault/failure. Design for the complete distribution upgrades to serve the development is in progress. The developer will have a cost responsibility for new line extensions within the development, as well as replacement of some of the existing unjacketed cable. Construction is tentatively scheduled to commence during FY 26/27, or as soon as advance on construction is received from the developer.

Completion of all remaining reconductoring outside of developer requirements will occur during FY 28/29.

Budget Distribution Est. Amount
$6,500
$0
$0
$15,000
$328,500
$350,000
Electric Revenue $175,000
CIAC (Vista Serena) $175,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $350,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-37
80 224

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$450,000 $150,000 $150,000 $150,000
$0
$450,000 $150,000 $150,000 $150,000 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $450,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $450,000
CIAC $0
Funding Source Total
This project will assist with the continued monitoring and operation of the electric distribution facilities within the HFTD Tiers 2 & 3 areas. The California Public Utility Commission's Wildfire Safety Advisory Board (WSAB) recommended that utilities with electric transmission or distribution facilities in HFTDs make tangible improvements to the monitoring and operation of these facilities to reduce wildfire risk.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
BEU has been required to submit a Wildfire Mitigation Plan for review to the WSAB each year since 2020. Within this time, BEU has completed minor improvements to facilities in Banning Canyon (water canyon) and has applied for grant funding to upgrade facilities within Mias Canyon. BEU is obligated to continue fire mitigation efforts, and has identified the use of reclosers as a high priority solution for circuits that enter the HFTD. BEU anticipates construction to begin during FY 26/27, and continue annually until grid hardening solutions have been met. BEU will continue to search for and apply for grant funding to offset revenue expenditures.

Budget Distribution Est. Amount
$25,000
$0
$0
$5,000
$420,000
$450,000
Project Title:

BEU will complete improvements to control of electricity in the Tiers 2 & 3 High Fire Threat District (HFTD). BEU will begin with the installation of distribution circuit reclosers to allow power to be shut off to these areas in the event that an imminent threat to public safety becomes present.

Estimated Completion Date:

Fire Mitigation Improvements in High Fire Threat District 6/30/2029 Project Description:
5-38
81 225

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$0
$2,100,000 $2,100,000
$2,100,000 $2,100,000 $0 $0 $0 $0 $0
Engineering
$2,100,000
$45,000
$1,860,000
Funding Plan:

Funding Source Total
Electric Revenue $0
CIAC (Grant)
Brandon Robinson, Electric Engineering Supervisor
Total $2,100,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Project Status:

Photo/Exhibit/Vicinity Map
The result from the Apple Fire in 2020 prompted BUE to search for funding to complete much needed upgrades/line hardening in areas within the service territory that are most susceptible to fire ignition. BEU began the design and grant application process for this project in 2021, and is currently awaiting funding after various design and environmental clearance activities. This project will be grant-funded thru the federal government's Hazard Mitigation Grant Program at 75% of total project cost, with 25% matching contributions form California Governor's Office of Emergency Services (CalOES) to complete the full 100% funding. Construction start for this project is dependent upon the grant funding during FY 26/27, in which BEU will be given 24 months to complete.

Budget Distribution Est. Amount
$185,000
$0
$10,000
$2,100,000
Project Title:

This project involves replacing 75 utility poles with new fire retardant-treated poles; replacing wooden crossarms on poles with fiberglass crossarms; installing insulated/covered wire and jumpers; installing covered insulators; installing line protection measures; and completing hazardous fuels reduction.

This project will help provide redundancy on our 34.5kV and 12.47kV and assist providing a point of connection to the 34.5kV system for the proposed substation to support expansion in the eastern part of the City.

Estimated Completion Date:

Mias Canyon Line Hardening 12/30/2028
Project Description:
5-39
82 226

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$2,000,000 $1,000,000 $1,000,000
$2,000,000 $0 $0 $1,000,000 $1,000,000 $0 $0
Engineering
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits on Hathaway St and new utility service extensions to accomodate new industrial development.

This project is fully dependent on the completion of this development.

Estimated Completion Date:

34.5kV/12.47kV/fiber Underground Circuits Hathaway St from Williams St to Hoffer St 6/30/2030 Project Description:

This project will accommodate street improvements required by the Sansone Group and First Hathaway Industrial warehouse developments. This will also assist with beautification of the eastern corridor due to the undergrounding of BEU utilities.

Project Status: Photo/Exhibit/Vicinity Map
BEU has completed UG conversion of facilities from Ramsey St to Williams St along Hathaway St in 2022. Design for this project is in progress. The developers will have a full responsibility for relocation/conversion along Hathaway St and new line extensions within the development. Construction is tentatively scheduled to commence during FY 28/29, or as soon as advance on construction is received from the developer.

Budget Distribution Est. Amount
$55,000
$0
$0
$35,000
$1,910,000
$2,000,000
Electric Revenue $0
CIAC (Sansone/First Hathaway) $2,000,000
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $2,000,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-40
83 227

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$175,000 $20,000 $130,000
$0
$175,000 $20,000 $0 $130,000 $0 $0 $0
Engineering
Project Title:

Underground conversion of 34.5kV, 12.47kV and fiber optic circuits thru easement within Banning Airport property from Lincoln St to John St.

Estimated Completion Date:

34.5kV/12.47kV/fiber Underground Circuits Lincoln St to John St 6/30/2029 Project Description:

This project will help provide redundancy on our 34.5kV and 12.47kV and assist providing a point of connection to the 34.5kV system for the proposed substation to support expansion in the eastern part of the City.

Project Status: Photo/Exhibit/Vicinity Map
In 2015, BEU completed a line extension thru an existing utility easement on the airport property to accommodate future redundancy needs. BEU has also completed UG line extensions to new facilities in the area which began in 2021. As the City continues to build out, more capacity will be needed in East Banning. Design for this project should begin early 2027. There may be a design/construction cost responsibility for future developers, but that cost is still unknown. BEU anticipates construction to commence during FY 28/29, as the need for additional capacity may become a requirement.

Budget Distribution Est. Amount
$20,000
$0
$0
$5,000
$125,000
$150,000
Electric Revenue $150,000
CIAC $0
Funding Source Total
Funding Plan:
$0
Brandon Robinson, Electric Engineering Supervisor
Total $150,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
5-41
84 228

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$850,000 $425,000 $425,000
$0
$850,000 $0 $425,000 $425,000 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $850,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $850,000
CIAC $0
Funding Source Total
This project will provide a much needed infrastructure upgrade for a critical 69/34.5kV/12.47kV/fiber pole line that contains the capacity to support 2/3 of BEU's total energy demand. This pole line carries transmission to Midway and Subset Substations which account for the largest loads within BEU's service territory.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
In 2014, BEU completed a relocation of the steel pole transmission line at Sunset Ave and Lincoln Street. The final phase of this project was to be completed prior to 2017, however budget constraints prevented the completion of the project. There may be a design/construction cost responsibility for future developers, but that cost is still unknown. BEU anticipates construction to commence during FY 28/29, which is anticipated to coincide with commercial development within the area.

Budget Distribution Est. Amount
$60,000
$0
$50,000
$35,000
$705,000
$850,000
Project Title:

Installation of two engineer-base steel pole to support 69/ 34.5kV, 12.47kV and fiber optic circuits on the west side of Sunset Ave north of Lincoln St.

Estimated Completion Date:

Engineered Base-Plate Poles at Sunset and Lincoln 6/30/2029 Project Description:
5-42
85 229

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$250,000 $250,000
$250,000 $0 $250,000 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $250,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $250,000
CIAC (Grant) $0
Funding Source Total
This project will allow BEU to improve redundancy and reliability within the system by isolating outages to a smaller area and reduce power restoration times.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
Planning and equipment research for this project began in 2022 and will continue with the completion of a system impact study of the current electric grid. BEU will vet different equipment manufacturers and determine the best method for initiating the pilot. The project will be constructed using BEU's in-house power line construction services. The pilot will include investigation and implementation of distribution automation (DA) solutions to provide communication with the field devices that are installed. BEU anticipates this pilot to begin in FY 27/28.

Budget Distribution Est. Amount
$35,000
$0
$0
$5,000
$210,000
$250,000
Project Title:

BEU will complete a pilot project to install reclosers and other sectionalizing devices on the distribution and sub-transmission system.

Estimated Completion Date:

Install Reclosers on 34.5 kV and 12.47 kV system 6/30/2028 Project Description:
5-43
86 230

CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$106,250 $106,250
$318,750 $318,750
$425,000 $318,750 $106,250 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $425,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $106,250
CIAC $318,750
Funding Source Total
This project will be required to rebuild BEU's distribution circuit around Robertson's Ready Mix's expanded mining site that was previously removed. BEU will regain the loss in capacity and redundancy in the system be completing this circuit re-build.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
BEU is negotiating a line extension agreement with Roberston's Ready Mix to complete the circuit re-route around the expanded mining area north of Hoffer St and west of Hathaway St. BEU has already completed removal of utility poles in conflict with the new mining activities in anticipation of beginning the construction of the circuit re-rout by 2025. There will be a design/construction cost responsibility for Robertson's that will total 75% or more of total project costs. BEU anticipates construction to commence during FY 26/27 and be completed in the following fiscal year.

Budget Distribution Est. Amount
$65,000
$0
$0
$15,000
$345,000
$425,000
Project Title:

Re-route/rebuild of 34.5kV, 12.47kV and fiber optic circuits around the Robertson's Ready Mix mining site.

Estimated Completion Date:

Robertson's Ready Mix Circuit Re-route 6/30/2028
Project Description:
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CITY OF BANNING
5 YEAR CAPITAL IMPROVEMENT PROGRAM (FY 2027- 2031)
Project Benefit:

Project Budget:

Design/Engineering/Enviro.

Right of Way Acquisition
Construction Support (e.g. survey, soils, etc.)
Construction Management/Inspections
Construction
Total

Funds FY 2027 FY 2028 FY 2029 FY 2030 FY 2031

Funds
$0
$3,500,000 $2,500,000 $1,000,000
$3,500,000 $2,500,000 $1,000,000 $0 $0 $0 $0
Engineering
$0
Brandon Robinson, Electric Engineering Supervisor
Total $3,500,000
Department: Division: Contacts:

Electric Fred Lyn, Deputy Electric Utility Director
Electric Revenue $0
CIAC (Grant) $3,500,000
Funding Source Total
This project will accommodate roadway improvements to connect Sun Lakes Blvd from Highland Home Road to Sunset Ave.

Project Status:

Funding Plan:

Photo/Exhibit/Vicinity Map
Planning and field investigation for this project started in 2021. BEU completed a design to convert overhead facilities to underground construction to accommodate the roadway extension. The project was bid to a construction contractor and approved by City Council in late 2025. Since BEU is obligated to continue fire mitigation efforts, improvements to the overhead infrastructure that will remain will include line hardening elements to protect from and prevent wildfire in the HFTD. BEU anticipates construction to begin toward the end of FY 26/27, and continue thru FY 27/28. Electric improvements for this project will be grant funded.

Budget Distribution Est. Amount
$125,000
$0
$0
$50,000
$3,325,000
$3,500,000
Project Title:

BEU will relocate transmission, distribution, and fiber optic infrastructure on Westward Ave/Sun Lakes Blvd due to roadway improvements. This project will include both underground conversion and overhead line hardening as these improvements will occur in the Tier 2 High Fire Threat District (HFTD).

Estimated Completion Date:

Sun Lakes Blvd Extension - Electric Relocation 12/30/2027 Project Description:
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.6 – Substation Capacity Analysis
The table below represents the substation capacity analysis based on the 2030 substation demand forecast. As shown in the table, the Midway, San Gorgonio, and Sunset summer forecast exceeds the base rating of their respective transformer; however, the forecast does not exceed the max rating of the transformer, therefore, no substation improvements are required in the 5- Year CIP.

The table also shows that the BEU system non-coincident peak exceeds the SCE Banning substation transformer base capacity for the summer and winter forecast and also the max capacity in the summer. Based on the non-coincident forecast, the total BEU system load is expected to exceed the max capacity by the summer of 2026. It is recommended that BEU continue to coordinate with SCE on the substation transformer capacity and develop a plan to increase the substation transformer capacity through the end of the forecast period.

Table 5.6-1 – Substation Capacity Analysis
2030 Transformer Transformer Transformer Transformer Transformer Transformer kW
Demand Base Max High Side Low Side % Capacity % Capacity Forecast MVA MVA kV kV Base Max
22nd Street
S 11,270 15 25 34.4 12.47 75% 45%
W 8,672 18 29 48% 30%
Ivy
S 6,598 15 25 69x34.4 12.47 44% 26%
W 5,604 18 29 31% 19%
Midway
S 17,197 2 x 7.5 2 x 9.375 34.4 12.47 115% 92%
W 11,040 18 22 61% 51%
San
Gorgonio
S 21,465 2 x 10 2 x 14 69x34.5 12.47 107% 77%
W 19,809 24 32 83% 62%
Stagecoach
S 7,397 10 12.5 69x34.5 12.47 74% 59%
W 4,196 12 14 35% 29%
Sunset
S 15,077 15 25 69x34.5 12.47 101% 60%
W 10,064 18 29 56% 35%
SCEBanning
S 63,576 2 x 21 2 x 28 34.5 151% 114%
W 53,737 50.4 64 107% 83%
Notes:

1. Individual substation kW Demand forecast shown as the non-coincident peak.

2. SCE-Banning kW Demand forecast shown as the coincident peak.

3. Base winter rating determined by IEEE C57.91-1995, Table 4 (1% increase per °C)

4. Max winter rating determined by IEEE C57.91-1995, Table 4 (0.75% increase per °C) 5-46
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.7 – Distribution System Analysis
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include 14 projects to switch load to adjacent lines to reduce single-phase line loading at a total estimated cost of $41,700, 2 projects for new line construction of 600’ totaling $336,400, 9 projects for singlephase to three-phase line rebuild of 10,107’ totaling $2,142,100, and 2 projects for three-phase line rebuild using larger conductor of 2,130’ totaling $285,500. The total estimated cost for distribution system improvements is $2,805,700.

The following pages detail the recommended distribution system improvements by substation and circuit.
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
22ND STREET SUBSTATION
CKT 63
CIP-1
Issue: UG146168, 1Ø, #2 URD line with 36 amps, 94 thru consumers.

Resolution: Close switch at vault 143589 at the intersection of Weather Way and Spring Pl. and open at the transformer at pad 146130 at the intersection of Summer Set Cir. and Amper Sky St. and feed load along Autumn Ln. from SW145671-B. Estimated cost: $2,300 (2030).

Image 5.7-1 – CIP Project 1
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-2
Issue: UG33x363, 1Ø, 1/0 URD line with 49 amps, 102 thru consumers.

Resolution: BEU will inspect the facilities at the intersection of Lake Buena Vista Way and Birdie Dr. and switch some of this B phase load along Lake Buena Vista Way west of Birdie Dr. to the 3Ø line that runs along Birdie Dr. Estimated cost: $2,000 (2028).

Image 5.7-2 – CIP Project 2
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-3
Issue: UG29v17, 1Ø, 1/0 URD with 97 amps, 239 thru consumers.

Resolution:
• Close switch at vault 101946 and open at vault 102621 at the intersection of Indian Canyon Dr. and Masters Dr. and backfeed all load north from SW103762-A. • Close switch at pad 103628 and open at pad 103513 to switch load south from pad 103628A.
• Install 3Ø vault at the intersection of Indian Canyon Dr. and Birdie Dr. and change feed of UG33x433 from 3Ø line along Birdie Dr. to feed all load along Indian Canyon Dr. west of Birdie Dr. from the 3Ø vault. Estimated cost: $5,900 (2026).

Image 5.7-3 – CIP Project 3
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-4
Issue: UG18v9, 1Ø, 1/0 URD with 96 amps, 230 thru customers.

Resolution:
• Change feed of line along Bradley St. to feed from 3Ø junction box and connect UG133185 by closing a switch at vault 103523 and open at the intersection of Sawgrass Dr. and Litchfield Ct. to serve all load north of vault 103523. • Backfeed UG109597 from 3Ø UG4550 and open around UG33x474 along Brackenridge Ave. Estimated cost: $4,000 (2027).

Image 5.7-4 – CIP Project 4
CKT 64
Issue: None

IVY SUBSTATION
CKT 11
Issue: None
CKT 12
Issue: None
CKT 13
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
Issue: None

MIDWAY SUBSTATION
CKT 21
CIP-5
Issue: UG33x282, 1Ø, #2 URD with 65 amps, 97 thru consumers.

Resolution:
• Construct a new, 300’, 1Ø, 1/0 AL URD primary voltage tie from pad 42503 to pad 42498, crossing W. Pinehurst Dr. and following S. Shoal Creek St. • Open the line at pad 42491 and serve all load to the west from the 1Ø line at S. Shoal Creek St. and Riveria Ave. Estimated cost: $114,600 (2027).

Image 5.7-5 – CIP Project 5
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-6
Issue: UG33x149, 1Ø, 2 URD with 64 amps, 86 thru consumers.

Resolution: Replace 600’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from vault 36857 along Rivera Ave. just south of Bermuda Dunes Ave to vault 36879 at the intersection of W. Forest Oaks Ave and W. Glen Abbey Way and split the load between multiple phases. Estimated cost: $223,300 (2027).

Image 5.7-6 – CIP Project 6
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-7
Issue: UG117v, 1Ø, #2 URD with 41 amps, 65 thru consumers.

Resolution Construct a new, 600’, 1Ø, 1/0 URD primary voltage tie from vault 41797 to pad 41823. Open at pad 41830 and switch all load southeast of Nicklaus Dr. along Hogan Ave. to feed from pad 41797. Estimated cost: $221,800 (2028).

Image 5.7-7 – CIP Project 7
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-8
Issue: UG33x244, 1Ø, 1/0 URD with 58 amps, 84 thru consumers.

Resolution: Close switch at vault 40252 and open at pad 40237 along Woodland Dr. to split west of Woodland Dr. to feed from vault 40252. Estimated cost: $2,100 (2028).

Image 5.7-8 – CIP Project 8
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-9
Issue: UG33x232, 1Ø, 1/0 URD with 37 amps, 41 thru consumers.

Resolution: Close BØ at pad 40257 along Fairway Oaks Ave. and open Transformer303 at the intersection of Mission Hills Dr. and Cooper Creek Dr. and feed load along Mission Hills Dr. from pad 40257. Estimated cost: $2,100 (2030).

Image 5.7-9 – CIP Project 9
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-10
Issue: UG33x199, 1Ø, 1/0 URD with 100 amps, 98 thru consumers (A phase), UG33x195, 1Ø, 1/0 URD with 114 amps, 162 thru consumers (B phase), and UG33x184, 1Ø, 1/0 URD with 74 amps, 99 thru consumers (C phase).

Resolution:
• Close switch at vault 38245 and open at vault 38212 at the intersection of Spring Hills Cr.

And Sheehan Cir. and backfeed all load west of Sheehan Cir. from vault 38245. • Change the feed of UG33x189 to feed from another phase at the 3Ø vault 38191 at the intersection of Riveria Ave. and Sunningdale St.
• Change feed of UG33x190 to feed from another phase at the 3Ø vault 38240 along Birdie Dr.
• Change feed of UG33x212 to feed from another phase at the 3Ø vault 38191 at the intersection of Riveria Ave. and Sunningdale St.
• Change feed of UG33x211 to feed from the 3Ø pad 38237 at the intersection of Cog Hill Rd. and Breckenridge Ave. and open at pad 38248 and feed all load to the west along Breckenridge Ave. to feed from pad 38237. Estimated cost: $6,700 (2026).

Image 5.7-10 – CIP Project 10
CKT 22
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 23
CIP-11
Issue: UG33x71, 1Ø, 1/0 URD with 37 amps, 77 thru consumers.

Resolution:
• Replace 1,300’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from pullbox Pb32117 along W.

Wilson St. to vault 32103 at the intersection of Marian Way and Dawn Way. • Close switch at marker M32898 along Beverly Dr. and open at pad 35930 along Evelyn Dr. Estimated cost: $547,600 (2030).

Image 5.7-11 – CIP Project 11
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 24
CIP-12
Issue: UG33x101, 1Ø, 1/0 URD with 61 amps, 93 downline customers.

Resolution: Close switch at pad 34934 and openUG33x118 at pad 34956 the intersection of Twin Hills Dr. and Links Ave. and backfeed load along Big Springs Dr. to feed from 3Ø lie to north at switch pad 34934. Estimated cost: $2,100 (2027).

Image 5.7-12 – CIP Project 12
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

SAN GORGONIO SUBSTATION
CKT 51
CIP-13
Issue: OH189362, 1Ø, #4 CU line with 105 amps, 174 thru consumers.

Resolution: Rebuild 1,391’ of 1Ø, #4 Cu line to 3Ø, 1/0 ACSR along W. Nicolet St. from pole number 189371 to pole number 192590. Estimated cost: $172,200 (2026).

Image 5.7-13 – CIP Project 13
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-14
Issue: OH206564, 1Ø, #4 CU line with 68 amps, 106 thru consumers.

Resolution: Rebuild 1,183’ of 1Ø, #4 and #6 CU line to 3Ø, 1/0 ACSR along N. 12th St. from pole number 190013 to pole number 158883. Estimated cost: $148,700 (2027).

Image 5.7-14 – CIP Project 14
CKT 52
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 53
CIP-15
19 Issue: UG295266, 3Ø, 750 MC URD conductor reaches 63% capacity.

Resolution: Open after OH240725 and close switch at Pole23857 and reconfigure SG233747 to 4=CLOSED, 3=CLOSED, 2=CLOSED and 1=OPEN to switch load to the Ivy substation. Estimated cost: $2,000 (2026).

Image 5.7-15 – CIP Project 15
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 54
CIP-16
Issue: UG295263, 3Ø, 750 MCM feeder exit and 336 ACSR exceeds 60% capacity thru OH252561 (67% capacity is the highest).

Resolution:
• Disconnect line section OH2138 from OH2137 (line heading north on N. Alessandro St. north of E. Williams St.) and close switch at Pole284048 (along N. Alessandro St. between George St. and E. Wilson St.).
• Change the feed of line section OH194778 to feed from OH2138 (which will now be fed from Stagecoach CKT 8) and serve all the load along E. Williams St. west of N. Alesandro St. to feed from Stagecoach CKT8. Estimate cost: $3,400 (2029).

Image 5.7-16 – CIP Project 16
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

STAGECOACH SUBSTATION
CKT 7
CIP-17
Issue: OH259474, 1Ø, #6 Cu line with 41 amps, 80 thru consumers.

Resolution: Rebuild 871’ of 1Ø, #6 CU line to 3Ø, 1/0 ACSR along E. Theadore St. from pole number P6970COB to pole number P2891COB. Estimated cost: $119,800 (2029).

Image 5.7-17 – CIP Project 17
5-64
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-18
Issue: OH268700, 1Ø, #4 ACSR line with 46 amps, 105 thru consumers.

Resolution: Rebuild 1,790’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR along E. Nicolet St. from pole number P6956COB to pole number Pole194713. Estimated cost: $236,700 (2029).

Image 5.7-18 – CIP Project 18
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-19
Issue: OH255103, 1Ø, #4 ACSR line with 41 amps, 80 thru consumers.

Resolution: Rebuild 1,417’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR along E. Nicolet St. from pole number P6956COB to pole number FP255128. Estimated cost: $193,400 (2029).

Image 5.7-19 – CIP Project 19
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 8
CIP-20
Issue: OH280416, 1Ø, 1/0 ACSR line with 36 amps, 61 consumers.

Resolution: Rebuild 955’ of 1Ø, 1/0 ACSR and #2 ACSR line to 3Ø, 1/0 ACSR beginning on E.

Indian School Ln. then heading north to E. Repplier Rd. from pole number P1344COB to pole number 280435. Estimated cost: $134,300 (2030).

Image 5.7-20 – CIP Project 20
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

SUNSET SUBSTATION
CKT 72
CIP-21
Issue: UG278161 Feeder Exit, 3Ø, 750 MCM URD conductor reaches 70% capacity.

Resolution: It is recommended to serve the Crestwood Communities load addition from CKT 77 at UG3.
• Change the feed of UG6 for the load along Mocking Bird Ln. to CKT 77 at vault SV100086. • Change the feed of UG18 for the load along Hillside Dr. to CKT 77 at vault SV100180. • Change the feed of UG33 for the load along Evergreen Ln. to CKT 77 at vault SV100084. • Change the feed of UG82 for the load along Oak Ln. to CKT 77 at junction box Pb20340.

Estimated cost: $2,800 (2026).

Image 5.7-21 – CIP Project 21
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-22
Issue: UG59v, 1Ø, 1/0 URD with 56 amps, 177 thru consumers.

Resolution: Close switch at pad 23132 along Mc Govern Ave. and open at pad 253139 and switch all load south and east to serve from pad 23132 along Mc Govern Ave..

Estimated cost: $2,100 (2028).

Image 5.7-22 – CIP Project 22
5-69
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-23
Issue: UG5v1, 1Ø, 4/0 URD with 55 amps, 174 thru consumers.

Resolution: Close switch at pad 23137 along W. Wilson St. and open at PAD 23138 along Bunker Hill Rd. and serve all load along Catchen Rd. from pad 23137. Estimated cost: $2,100 (2028).

Image 5.7-23 – CIP Project 23
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-24
Issue: OH71, 3Ø, 4/0 ACSR conductor reaches 75% capacity and continued to be greater than 60% capacity thru OH143.

Resolution: Rebuild 1,693; of 3Ø, 4/0 ACSR line to 3Ø, 336 ACSR along W. Wilson St. from pole number 14759 to pole number 14817. Estimated cost: $219,300 (2026).

Image 5.7-24 – CIP Project 24
5-71
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CIP-25
Issue: OH183168, OH183140, and OH183149, 3Ø, #4 ACSR conductor reaches 60% capacity.

Resolution: Rebuild 437’ of 3Ø, #4 CU line to 3Ø, 336 ACSR along N. 16th St. between W.

Nicolet St. and W. Wilson St. from pole number 183146 to pole number Pole183139. Estimated cost: $66,200 (2030).

Image 5.7-23 – CIP Project 25
CKT 74
Issue: None
5-72
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 76
CIP-26
Issue: UG43v, 1Ø, 1/0 URD with 39 amps, 95 thru consumers.

Resolution: Replace 650’ of 1Ø, 1/0 URD line with 3Ø, 1/0 URD line from vault 28573 along W. Wilson St. to vault 28595 at the intersection of W. Hoffer St. and Foothill Dr.

Estimated cost: $336,100 (2029).

Image 5.7-26 – CIP Project 26
CKT 77
Note: The feeder extends along Mountain Ave. along with CKT 72 but does not have any load connected. SEE CKT 72 recommendations.

BANNING SUBSTATION (34.5 kV Analysis)
CKT 1
Issue: None
CKT 2
Issue: None
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP
CKT 3
CIP-27
Issue: The model shows CKT 3 feeding the Midway, Ivy, and Stagecoach substations.

OH248992 Feeder Exit, 3Ø, 336 ACSR reaches 95% capacity, OH2296, 3Ø, 4/0 ACSR reaches 78% capacity, and OH2316, 3Ø, 4/0 ACSR reaches 62% capacity.

Resolution: Close the tie around Pole241891 and open the line at Pole262449 to switch load from CKT 3 to CKT 1. This will change the feed of the Stagecoach substation to be served by CKT1. Estimated cost: $2,100 (2026).

Image 5.7-27 – CIP Project 27
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
5-YEAR CIP

5.8 – Total Cost Estimate
The table below contains a breakdown of the total estimated cost of the 5-Year CIP.

Table 5.8-1 – Total 5-Year CIP Cost Estimate
2026-2030 CIP
2026 2027 2028 2029 2030 Totals
OH Maintenance Program
Total Cost $604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $604,198 $622,324 $640,994 $1,079,272 $1,111,650 $4,058,438 Capital-Maintenance Projects
Total Cost $5,460,000 $3,154,500 $1,690,000 $4,980,000 $5,500,000 $20,784,500 CIAC $4,918,750 $1,000,000 $0 $2,375,000 $1,000,000 $9,293,750 BEU Funding Cost $541,250 $2,154,500 $1,690,000 $2,605,000 $4,500,000 $11,490,750 System Improvements Projects
Total Cost $411,000 $492,700 $230,100 $919,400 $752,500 $2,805,700 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $411,000 $492,700 $230,100 $919,400 $752,500 $2,805,700 5-year CIP Cost
Total Cost $6,475,198 $4,269,524 $2,561,094 $6,978,672 $7,364,150 $27,648,638 CIAC $4,918,750 $1,000,000 $0 $2,375,000 $1,000,000 $9,293,750 BEU Funding Cost $1,156,448 $3,269,524 $2,561,094 $4,603,672 $6,364,150 $18,354,888 For the BEU funding cost, 22% is for OH Maintenance Program, 63% is for Capital Maintenance Projects, and 15% is for System-Improvement Projects.
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN

6.0 – 15 – YEAR ESMP

6.1 – Overhead Maintenance Program
The Overhead Maintenance Program includes the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect 20 poles per week for the years 2031 thru 2035 and 25 poles per week for the years 2036 thru 2045. This totals to 1,040 poles inspected per year between 2031 and 2035 and 1,300 poles inspected between 2036 and 2045 for a grand total of 18,200 poles inspected for the duration of the 15-Year ESMP. An estimated cost of $322 per pole inspection was used for 2031 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole inspections for the 15-Year ESMP is $7,350,010.

It is projected that BEU will replace 100 poles per year for the years 2031 thru 2045. This totals to 1,500 poles replaced for the duration of the 15-Year ESMP. An estimated cost of $8,935 per pole replacement was used for 2031 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole replacements for the 15-Year ESMP is $16,618,732.

The total estimated cost for the Overhead Maintenance Program for the 15-year ESMP is $23,968,742. The table below shows a breakdown of the Overhead Maintenance Program.

Table 6.1-1 – Overhead Maintenance Program Costs 2031 thru 2035 2031 2032 2033 2034 2035 Total
Number of
Poles
Inspected
1,040 1,040 1,040 1,040 1,040 5,200
Cost per
Inspection �‬‮‮ �‬‬‮ �‬‮ �‬‮ �‬‬ -
Total Cost of
Inspection $335,290 $345,349 $355,709 $366,380 $377,372 $1,780,100 Number of
Poles
Replaced
100 100 100 100 100 500
Cost per
Replacement $8,935 $9,203 $9,479 $9,764 $10,057 -
Total Cost of
Replacement $893,532 $920,338 $947,949 $976,387 $1,005,679 $4,743,885 6-1
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
Table 6.1-2 – Overhead Maintenance Program Costs 2036 thru 2040 2036 2037 2038 2039 2040 Total
Number of Poles
Inspected 1,300 1,300 1,300 1,300 1,300 6,500
Cost per Inspection $374 $385 $397 $408 $421 -
Total Cost of
Inspection $485,866 $500,442 $515,455 $530,919 $546,847 $2,579,529 Number of Poles
Replaced 100 100 100 100 100 500
Cost per
Replacement $10,358 $10,669 $10,989 $11,319 $11,659 -
Total Cost of
Replacement $1,035,849 $1,066,924 $1,098,932 $1,131,900 $1,165,857 $5,499,463 Table 6.1-3 – Overhead Maintenance Program Costs 2041 thru 2045 2041 2042 2043 2044 2045 Total
Number of Poles
Inspected 1,300 1,300 1,300 1,300 1,300 6,500
Cost per Inspection $433 $446 $460 $473 $488 -
Total Cost of
Inspection $563,252 $580,150 $597,554 $615,481 $633,945 $2,990,381 Number of Poles
Replaced 100 100 100 100 100 500
Cost per
Replacement $12,008 $12,369 $12,740 $13,122 $13,515 -
Total Cost of
Replacement $1,200,833 $1,236,858 $1,273,964 $1,312,182 $1,351,547 $6,375,384 6-2
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CITY OF BANNING ELECTRIC UTILITY

ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

6.2 – CAPITAL MAINTENANCE PROJECTS
BEU has identified 6 Capital Maintenance Projects to include in the 15-year ESMP. The total estimated cost for these projects is $8,350,000. It is projected that BEU will receive $3,000,000 in contributions in aid to these projects bringing the total BEU funding cost to $5,350,000.

The following tables list the Capital Maintenance projects that have been identified for inclusion to the 15-year ESMP.

Table 6.2-1 – Capital Maintenance Project Costs
Project Description Year Total Cost CIAC
BEU
Funding
Cost
Midway Substation Upgrades (breaker
replacement and SCADA-ready
upgrades and future full replacement)
2031 $1,000,000 $0 $1,000,000

34.5/12.47/fiber Relocation on 4th St
from Westward Ave to Lincoln St 2031 $1,500,000 $1,500,0001 $0 Underground Conversion from
Apex/Ramsey to Joshua Palmer 2031 $850,000 $0 $850,000
Underground Conversion at Wilson St
from Smith Creek to Highland Home Rd 2031 $500,000 $0 $500,000

34.5/12.47/fiber I-10 Crossing at
Hathaway from John St to Ramsey St 2031 $1,500,000 $1,500,0002 $0 Overhead Transmission System
Extension (Hoffer/Hathaway to
Stagecoach Substation)
2031-
2032 $3,000,000 $0 $3,000,000
Total 15-Year ESMP Capital Maintenance Cost $8,350,000 $3,000,000 $5,300,000 1 Up to 100% funding from Rancho San Gorgonio Development 2 Up to 100% funding from Hillwood Development
6-3
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

6.3 – SUBSTATION CAPACITY ANALYSIS
The table below represents the substation capacity analysis based on the 2045 substation demand after distribution system improvements including adding the new Smith Creek Substation, new feeders out of Stagecoach and Sunset, and load switching recommendations.

As shown in the table, the San Gorgonio, Stagecoach, and Sunset substations summer projected peak exceeds the base rating of their respective transformer; however, with the exception of the Stagecoach Substation, the load does not exceed the max rating of the transformer. For the Stagecoach Substation, it is recommended to replace the existing base 10 MVA transformer with a base 15 MVA transformer before the summer 2040 peak. With this improvement, the projected load will not exceed the base rating or the max rating of the new transformer thru the end of this ESMP.

The table also shows that the BEU system non-coincident peak exceeds the SCE Banning substation transformer base capacity for the summer and winter forecast and also the max capacity in the summer. Based on the non-coincident forecast, the total BEU system load is expected to exceed the max capacity by the summer of 2026. It is recommended that BEU continue to coordinate with SCE on the substation transformer capacity and develop a plan to increase the substation transformer capacity through the end of the ESMP period.

Table 6.3-1 – Substation Capacity Analysis
2045 kW
Demand
Transformer
Base
Transformer
Max
Transformer
High Side
Transformer
Low Side
Transformer
% Capacity
Transformer
% Capacity
Forecast MVA MVA kV kV Base Max
22nd Street
S 6,250 15 25 34.4 12.47 42% 25%
W 4,809 18 29 27% 17%
Ivy
S 11,446 15 25 69x34.4 12.47 76% 46%
W 9,679 18 29 54% 34%
Midway
S 0 2 x 7.5 2 x 9.375 34.4 12.47 0% 0%
W 0 18 22 0% 0%
Smith Creek
S 32,566 2 x 20 2 x 37.5 69x34.4 12.47 81% 43%
W 20,906 48 75 44% 28%
San
Gorgonio
S 19,996 2 x 10 2 x 14 69x34.5 12.47 100% 71%
W 18,391 24 32 77% 57%
Stagecoach
S 14,764 10 12.5 69x34.5 12.47 148% 118%
W 8,374 12 14 70% 58%
Sunset
S 20,920 15 25 69x34.5 12.47 139% 84%
W 13,441 18 29 75% 47%
SCEBanning
S 90,738 2 x 21 2 x 28 34.5 216% 162%
W 75,580 50.4 64 150% 117%
Notes:

1. Individual substation kW Demand forecast shown as the non-coincident peak.

2. SCE-Banning kW Demand forecast shown as the coincident peak.

3. Base winter rating determined by IEEE C57.91-1995, Table 4 (1% increase per °C)

4. Max winter rating determined by IEEE C57.91-1995, Table 4 (0.75% increase per °C) 6-4
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

6.4 – DISTRIBUTION SYSTEM ANALYSIS
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing for the 15-year ESMP. The analysis results include 5 projects to switch load to adjacent lines at a total estimated cost of $17,100, 2 projects for new overhead line construction totaling $1,219,000, 9 projects for rebuilding overhead lines totaling $1,926,600, 10 projects for new underground line construction totaling $7,107,100 and 4 projects for replacing underground line with larger conductor totaling $1,269,500. The total estimated cost for distribution system improvements for the 15-year ESMP is $11,539,300.

The following pages detail the recommended distribution system improvements by substation and circuit.
6-5
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
22ND STREET SUBSTATION
CKT 63
ESMP-1
Issue: UG33x303, 1Ø, #2 URD line with 41 amps, 41 thru consumers.

Resolution:
• Replace 580’ of 1Ø, #2 URD line with 3Ø, 1/0 URD line from vault 44888 to pad 44888 along Indian Wells Rd.
• Split the load between multiple phases.
• Estimated cost: $345,600 (2041).

Image 6.4-1 – ESMP Project 1
6-6
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
ESMP-2
Issue: UG9v7, 1Ø, 1/0 URD line with 41 amps, 86 thru consumers.

Resolution:
• Construct 540’ of 1Ø, 1/0 URD line from pad 46153 to pad 108770 along Pauma Valley Rd. utilizing pull boxes Pb101706, Pb108810, PB108831, and Pb108819 • Open after line section UG9v9 at vault 108834
• Change the feed of line section UG33x490 along Eagle Trace Ln. at vault 108834 to feed from the north.
• Change the feed of UG33x489 along Warwick Hills Way at pad 108770 to feed from the north.
• Estimated cost: $388,100 (2045).

Image 6.4-2 – ESMP Project 2
CKT 64
Issue: None

IVY SUBSTATION
CKT 11
Issue: None
6-7
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
CKT 12
ESMP-3
Issue: OH239297, 3Ø, #2 ACSR OH conductor reaches 73% capacity.

Resolution: Rebuild 423’ of 3Ø, 1/0 ACSR and #2 ACSR line to 3Ø, 336 ACSR along E.

Westward Ave and crossing E. Woodward Ave from Pole239250 to Pole239296.

Estimated cost: $120,400 (2044).

Image 6.4-3 – ESMP Project 3
CKT 13
Issue: None

MIDWAY SUBSTATION
The new Smith Creek Substation is planned for construction beginning in 2030 with a planned energization in 2031. All of the load currently served by the Midway Substation will be switched to Smith Creek. See the Smith Creek Substation writeup for system improvements required to support the load.
6-8
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

SAN GORGONIO SUBSTATION
CKT 51
ESMP-4
Issue: UG295264, 3Ø, 750 MCM conductor at the feeder exit reaches 66% capacity and OH1359, 3Ø, 336 ACSR conductor along W Lincoln St. reaches 62% capacity.

Resolution: Open SW209315-A at FP197794 Along George St. between N. 3rd St. and N 2nd St. and switch a portion of load to the Stagecoach substation. Note: In order for this to be completed without further problems, CKT’s 5 and 6 out of the Stagecoach substation will be constructed. See the Stagecoach system improvement recommendations for projects required to complete this load switch. Estimated cost: $3,100 (2041).

Image 6.4-4 – ESMP Project 4
ESMP-5
Issue: OH189322, 1Ø, #6 CU line with 59 amps, 57 thru consumers.

Resolution: Rebuild 625’ of 1Ø, #6 and #4 CU line to 3Ø, 1/0 ACSR from Pole189367 to Pole198056 between W. Nicolet St. and W. Williams St. and just west of N. 6th St.

Once the line is rebuilt to three-phase, balance the taps between the three phases.

Estimated cost: $132,800 (2040).
6-9
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-5 – ESMP Project 5
CKT 52
Issue: None
CKT 53
ESMP-6
Issue: UG241798, 1Ø, 2 URD with 59 amps, 46 thru consumers.

Resolution: Open the single-phase line at Vault 146193 and backfeed the line at Pad 146238 to split up the single-phase line and serve from another source. Estimated cost:
$2,900 (2039).
6-10
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-6 – ESMP Project 6
ESMP-7
Issue: OH237438, 1Ø, #4 ACSR line with 57 amps, 34 thru consumers.

Resolution: Rebuild 3,155’ of 1Ø, #4 ACSR line to 3Ø, 1/0 ACSR from FP237936 to Pole237034 beginning at the intersection of S. Hargrave St. and Wesley St. and ending at the intersection of S. Hathaway St. and Porter St. Once the line is rebuilt to three-phase, balance the taps between the three phases. Estimated cost:
$539,700 (2038).
6-11
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-7 – ESMP Project 7
CKT 54
Issue: None

STAGECOACH SUBSTATION
CKT 5 & 6
In order to balance the load at the Stagecoach substation and also to switch load from the San Gorgonio and Sunset substations to reduce conductor loading, it is recommended to build out CKT’s 5 and 6 out of the Stagecoach substation. The projects listed below are recommended to construct CKT’s 5 and 6 along with switching load from Stagecoach CKT’s 7 and 8, San Gorgonio CKT 51, and Sunset CKT 72. The two need circuits will head south from the substation to E.

Theodore St., head west on E. Theodore St. to N. Alessandro St., head south on N. Alessandro St. to E. Hoffer St. and then head west on E. Hoffer St. and end just west of N. San Gorgonio Ave.

Circuit 5 will be express to this point.

ESMP-8
• Construct 2, 150’; 3Ø, 750 MCM feeder exits from Bay 5 and Bay 6 to pole P4301COB.

Estimated cost: $165,800 (2035).
6-12
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-8 – ESMP Project 8
ESMP-9
• Rebuild 200’ of 1Ø, #2 ACSR line to double circuit 3Ø, 477 ACSR from pole P4301COB to pole P4302COB along the substation back entrance road. • Create open point at pole P2999COB along E. Theodore St. and switch a portion of load from CKT 7 to the new CKT 6.
• Estimated cost: $57,500 (2035).
6-13
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-9 – ESMP Project 9
ESMP-10
• Rebuild 650’ of 3Ø, 1/0 ACSR line to double circuit 3Ø, 477 ACSR from pole P4302COB to pole GT68215 along E. Theodore St. from N. Hermosa Ave heading west to just past Vista Serna Ave. Estimated cost: $157,400 (2035).
6-14
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-10 – ESMP Project 10
ESMP-11
• Rebuild 900’ of 1Ø, #2 CU line to double circuit 3Ø, 477 ACSR from pole GT68215 to pole P2330COB along E. Theadore St. east of N. Alessandro St. Estimated cost: $181,800 (2035).
6-15
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-11 – ESMP Project 11
ESMP-12
• Construct 100’ of double circuit 3Ø, 477 ACSR line from pole P2330COB to pole P2331COB along E. Theadore St. east of N. Alessandro St. • Create open point at Pole282646 along N. Alessandro St. just north of E. Theodore St. and switch a portion of load from CKT 8 to CKT 6.
• Estimated cost: $31,800 (2035).
6-16
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-12 – ESMP Project 12
ESMP-13
• Rebuild 2,150’ of 3Ø, 336 ACSR line to double circuit 3Ø, 336 ACSR from pole P2331COB to Pole283017 heading south along N. Alessandro St and then west along W. Hoffer St. • At Pole283017, switch the tap heading north towards W. Gillman St. to CKT 5 and switch the tap heading south towards E. Wilson St. to CKT 6.
• Estimated cost: $455,400 (2035).
6-17
135 279

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-13 – ESMP Project 13
CKT 7
Issue: None
CKT 8
ESMP-14
Issue: OH282953, 1Ø, #4 CU line with 37 amps, 52 consumers.

Resolution: Rebuild 510’ of 1Ø, #4 CU line to 3Ø, 1/0 ACSR along E. Theodore St. west of N.

Alessandro St from pole P2331COB to pole 30733CWT. Estimated cost: $115,200 (2043).
6-18
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-14 – ESMP Project 14

SUNSET SUBSTATION
CKT 72
ESMP-15
Issue: UG278161 Feeder Exit, 3Ø, 750 MCM URD conductor reaches 95% capacity and is greater than 80% capacity thru UG20. OH71 3Ø, 336 ACSR reaches 76% capacity and is greater than 60% capacity thru OH165. OH162 3Ø, 4/0 ACSR reaches 80% capacity and is greater than 60% capacity thru OH156.

Resolution: It is recommended to open at Pole175357 at the intersection of N. 22nd St. and W.

Nicolet St. and close at Pole200537 along W. Gilman St. just west of N. 8th St. and switch load to the new Stagecoach CKT 5. Estimated cost: $2,800 (2036). 6-19
137 281

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-15 – ESMP Project 15
ESMP-16
Issue: With the load switch from Stagecoach CKT 72 to Stagecoach CKT 5 as described in ESMP-15, the 3Ø, #2 ACSR line at OH200538 reaches 101% Resolution: Rebuild 875’ of 3Ø, #2 ACSR line to 3Ø, 477 ACSR from Pole200537 to Pole213210 along W. Gilman St. between N. 8th St and 11th St. Estimated cost:
$166,400 (2037).
6-20
138 282

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-16 – ESMP Project 16
ESMP-17
Issue: OH213258, 1Ø, #2 ACSR line with 41 amps, 73 consumers Resolution: It is recommended to open at Pad 28196 and close at Pad 28229 and split the load between W. Gilman St. and W Hoffer St. west of N. 8th St. from two different threephase lines. Estimated cost: $3,400 (2042). 6-21
139 283

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-17 – ESMP Project 17
CKT 74
Issue: None
6-22
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
CKT 76
ESMP-18
Issue: Underground feeder exit, 3Ø, 750 MCM reaches 110% capacity and is greater than 60% capacity through UG2vQ6 at Vault 31064.

Resolution:
• Utilize CKT 78 and create a new feeder to serve the south west side of the Atwell Subdivision. See Image 6.4-20 below for the feeder plan recommendation. • Using the existing empty conduit that is in the same trench as CKT 76:
o Install 1,862’ of 3Ø, 750 MCM from the feeder bay exit to Vault LV100172 at the intersection of Highland Home Rd. and Mountain Ave. using the existing conduit. o Install 2,706‘ of 3Ø, 750 MCM from Vault LV100172 to Vault SP100103 along Highland Home Rd. north of Meadowline Way using the existing conduit and connect to cabinet #2 in switchgear SW12-2116 while removing the connection between Vault SP100102 cabinet #1 and Vault SP100103 cabinet #2. This will switch all load along Meadowline Way west of Highland Home Rd. to CKT 78. o Install 1,400’ of 3Ø, 750 MCM from Vault SP100109 cabinet 1 to Switchgear SG290766 following Meadowline Way.
o Open at Vault M98523 along N. Highland Springs Ave. and close SG290766 cabinet #2 along Meadowline Way and switch all load currently served from CKT 76 to the new CKT 78.
o Estimated cost: $927,000 (2031).

Image 6.4-18 – ESMP Project 18
6-23
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
EMSP-19
Issue: Despite the load switch to the new CKT 78, the underground feeder exit, 3Ø, 750 MCM is still over 60% capacity through Vault SP100105
Resolution:
• Utilize CKT 75 and create a new feeder to serve the south side of the Atwell Subdivision.

See Image 6.4-20 below for the feeder plan recommendation. • Using the existing empty conduit that is in the same trench as CKT 76:
o Install 1,862’ of 3Ø, 750 MCM from the feeder bay exit to Vault LV100172 at the intersection of Highland Home Rd. and Mountain Ave. using the existing conduit. o Install 2,706‘ of 3Ø, 750 MCM from Vault LV100172 to Vault SP100103 along Highland Home Rd. north of Meadowline Way using the existing conduit. o Install 2,953’ of 3Ø, 750 MCM from Vault SP100103 to Vault 30985 along W.

Wilson St. west of Highland Home Rd.
o At Vault 30985, switch the conductor heading west along W. Wilson St. to feed from the new CKT 75.
o Estimated cost: $1,032,400 (2032).

Image 6.4-19 – ESMP Project 19
6-24
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-20 – FEEDER PLAN FOR CKT’S 75, 76, AND 78
CKT 77
Issue: None

NEW SMITH CREEK SUBSTATION
The new Smith Creek substation is planned to be constructed at a property owned by the City of Banning on the south side of Interstate 10 and will replace the Midway substation on the north side of Interstate 10. Construction for the new Smith Creek substation will begin in 2030 with an energization date in 2031. All four feeders currently served by Midway will be switched to Smith Creek. Additionally, four new feeders will be added at Smith Creek to served planned load additions between Interstate 10 and Westward Ave. The projects below are recommended to construct the new feeders out of Smith Creek to serve the existing Midway feeders and support existing and future load additions. Refer to Image 6.4-32 for the Smith Creek feeder plan.

Smith Creek CKT 21
Circuit 21 will be constructed to serve the existing Midway CKT 21. 6-25
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
ESMP-20
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104936. • Create open point at Pole104876 and serve the load on the south side of Interstate 10. • Create an open point at Pole104926 along Highland Home Rd. between CKT 21 and 25 • Create an open point at pole P6554COB along Westward Ave. between CKT 21 and 25 • Create an open point at Vault 40257 along Fairway Oks Ave. just north of Mission Hills Dr. between CKT 21 and 25
• Tie the three-phase line together at Vault 38231 at the intersection of Birdie Dr. and Cog Hill Rd.
• Estimated cost: $144,400 (2031).

Image 6.4-21 – ESMP Project 20
Smith Creek CKT 22
Circuit 22 will be constructed to serve the existing Midway CKT 22 and CKT 23.

ESMP-21
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104876 and use the existing Midway CKT 21 Interstate 10 crossing to serve the existing Midway CKT 22.

Estimated cost: $139,600 (2031).
6-26
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-22 – ESMP Project 21
Smith Creek CKT 23
Circuit 23 will be constructed to serve the existing Midway CKT 23.

ESMP-22
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104936 • Chage the feed at Pole104936 from Midway CKT 23 to Smith Creek CKT 23 • Use the existing Midway CKT 24 Interstate 10 crossing as the new Smith Creek CKT 23 highway crossing.
• Tie Midway CKT 23 to Smith Creek CKT 23 inside the current Midway substation to switch all of Midway CKT 23 to Smith Creek CKT 23
• Estimated cost: $144,400 (2031).
6-27
145 289

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-23 – ESMP Project 22
ESMP-23
Issue: The 750 MCM conductor at the feeder exit will reach 79% capacity, the 336 ACSR and 477 ACSR line up to and crossing Interstate 10 will reach 80% capacity and 64% capacity respectively, and the 750 MCM conductor at the current Midway CKT 23 feeder exit and heading along W. Ramsey St. to Lori Way exceeds 60% capacity.

Resolution:
• Construct 800’ of 3Ø, 750 MCM URD line from Vault 320963 to Vault 34038 and up to riser Pole34020 along W. Ramsey St between Highland Home Rd. and Lori Way. • Rebuild 2,165’ of single circuit 3Ø, 336 ACSR to double circuit 3Ø, 336 ACSR from Pole34020 to Pole206642 along W. Ramsey St. between Lori Way and Memorial Dr. • Rebuild 175’ of single circuit 3Ø, 750 MCM URD line to double circuit 3Ø, 750 MCM from riser Pole206642 to Vault 204676 along W. Ramsey St. at Memorial Dr. • At Vault 204676, leave the tap heading west along W. Ramey St. connected to CKT 23 and change the feed of the tap heading north along Memorial Dr. to CKT 22 using the newly constructed line.
• In SG266801 at the intersection of W. Ramsey St. and N. Highland Springs Ave., open cabinet #3
• Connect the three-phase between Vault 204734 and Vault 204656 to change the feed to Smith Creek CKT 22.
• Estimated cost: $1,187,200 (2036).
6-28
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-24 – ESMP Project 23
Smith Creek CKT 24
Circuit 24 will be constructed to serve the existing Midway CKT 24.

ESMP-24
• Construct 300’ of 3Ø, 750 MCM URD from the feeder bay to Pole104900 and switch Midway CKT 24 to Smith Creek CKT 24. Estimated cost: $139,600 (2031). 6-29
147 291

CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-25 – ESMP Project 24
ESMP-25
Issue: UG1v, 3Ø, 1/0 URD line reaches 81% Capacity
Resolution: Replace 440’ of 3Ø, 1/0 URD with 3Ø, 750 MCM from Junction Box 34967 to Vault 34921 at the intersection of Northwood Ave. and Brooklawn Dr. Estimated cost:
$237,600 (2034).
6-30
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-26 – ESMP Project 25
Smith Creek CKT 25
Circuit 25 will be constructed to serve a portion of the existing Midway CKT 21.

ESMP-26
• Construct 2,745’ of double circuit 3Ø, 750 MCM URD line from the feeder bay to pole P6554COB at the intersection of Westward Ave. and S. Highland Home Rd. *Note, this will also be the route for Smith Creek CKT 26.
• At pole P6554COB, change feed from Midway CKT 21 to Smith Creek CKT 25. • Estimated cost: $1,652,900 (2031).
6-31
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-27 – ESMP Project 26
ESMP-27
Issue: UG1v24, 3Ø, 350 MCM URD conductor reaches 79% capacity.

Resolution: Replace 2,100’ of 3Ø, 350 AL MCM URD conductor with 3Ø, 750 MCM URD conductor from Vault 36923 located at the intersection of Sun Lakes Blvd. and Country Club Dr. and following Country Club Dr. to Vault 41797 at the intersection of Country Club Dr. and Hogan Ave. Estimated cost: $316,000 (2031). 6-32
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-28 – ESMP Project 27
Smith Creek CKT 26
Circuit 26 will be constructed to serve a portion of the existing Midway CKT 21 and 22nd Street CKT 63. See ESMP-26 for project to construct the circuit from Smith Creek.

ESMP-28
• Create open point at Pole104842 along Westward Ave to switch a portion of load from 22nd Street CKT 63
• At SG49762 along Country Club Dr. between Birdie Dr. and Gleneagles Dr., open cabinet #2 and change feed to Smith Creek CKT 25 at Vault 41797 along County Club Dr. at Hogan Ave.
• Estimated cost: $4,900 (2031).
6-33
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-29 – ESMP Project 28
ESMP-29
Issue: UG16v2, 3Ø, 350 MCM URD conductor reaches 70% capacity.

Resolution: Replace 2,420’ of 3Ø, 350 MCM URD with 3Ø, 750 MCM URD beginning at Pad 44570 along Sun Lakes Blvd, heading south on Country Club Dr. and ending at Vault 46131. Estimated cost: $370,300 (2033).
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-30 – ESMP Project 29
Smith Creek CKT’s 27 & 28
Circuits 27 and 28 will be constructed to serve new planned load in an area bordered by Interstate 10 and Westward Ave. on the north and south and Highland Home Rd. and Sunset Ave. on the east and west.

ESMP-30
• Construct 2, 3Ø, 750 MCM URD lines from the feeder bay heading due south from the substation to what will be the extension of W Lincoln St. and then heading east along W.

Lincoln St. to Sunset Ave at Pole104911. Estimated cost: $2,372,900 (2032). 6-35
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CITY OF BANNING ELECTRIC UTILITY
2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Image 6.4-31 – ESMP Project 30
Image 6.4-32 – Smith Creek Feeder Plan
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP

6.5 – TOTAL COST ESTIMATE
The tables below contain a breakdown of the total estimated cost of the 15-Year ESMP.

Table 6.5-1 – 15-Year ESMP Cost Estimate (2031-2035)
2031 2032 2033 2034 2035
OH Maintenance Program
Total Cost $1,228,822 $1,265,687 $1,303,658 $1,342,767 $1,383,050 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $1,228,822 $1,265,687 $1,303,658 $1,342,767 $1,383,050 Capital-Maintenance Projects
Total Cost $6,850,000 $1,500,000 $0 $0 $0
CIAC $3,000,000 $0 $0 $0 $0
BEU Funding Cost $3,850,000 $1,500,000 $0 $0 $0
System Improvement Projects
Total Cost $3,468,800 $3,405,300 $370,300 $237,600 $1,049,700 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $3,468,800 $3,405,300 $370,300 $237,600 $1,049,700 15-year ESMP Cost
Total Cost $11,547,622 $6,170,987 $1,673,958 $1,580,367 $2,432,750 CIAC $3,000,000 $0 $0 $0 $0
BEU Funding Cost $8,547,622 $6,170,987 $1,673,958 $1,580,367 $2,432,750 6-37
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Table 6.5-2 – 15-Year ESMP Cost Estimate (2036-2040)
2036 2037 2038 2039 2040
OH Maintenance Program
Total Cost $1,521,715 $1,567,367 $1,614,387 $1,662,819 $1,712,704 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $1,521,715 $1,567,367 $1,614,387 $1,662,819 $1,712,704 Capital-Maintenance Projects
Total Cost $0 $0 $0 $0 $0
CIAC $0 $0 $0 $0 $0
BEU Funding Cost $0 $0 $0 $0 $0
System Improvement Projects
Total Cost $1,190,000 $166,400 $539,700 $2,900 $132,800 CIAC $0 $0 $0 $0 $0
BEU Funding
Cost $1,190,000 $166,400 $539,700 $2,900 $132,800
15-year ESMP Cost
Total Cost $2,711,715 $1,733,767 $2,154,087 $1,665,719 $1,845,504 CIAC $0 $0 $0 $0 $0
BEU Funding Cost $2,711,715 $1,733,767 $2,154,087 $1,665,719 $1,845,504 6-38
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2026-2045 ELECTRIC SERVICE MASTER PLAN
15-YEAR ESMP
Table 6.5-3 – 15-Year ESMP Cost Estimate (2041-2045)
2041 2042 2043 2044 2045 Totals
OH Maintenance Program
Total Cost $1,764,085 $1,817,007 $1,871,518 $1,927,663 $1,985,493 $23,968,742 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $1,764,085 $1,817,007 $1,871,518 $1,927,663 $1,985,493 $23,968,742 Capital-Maintenance Projects
Total Cost $0 $0 $0 $0 $0 $8,350,000
CIAC $0 $0 $0 $0 $0 $3,000,000
BEU Funding Cost $0 $0 $0 $0 $0 $5,350,000
System Improvement Projects
Total Cost $348,700 $3,400 $115,200 $120,400 $388,100 $11,539,300 CIAC $0 $0 $0 $0 $0 $0
BEU Funding Cost $348,700 $3,400 $115,200 $120,400 $388,100 $11,539,300 15-year ESMP Cost
Total Cost $2,112,785 $1,820,407 $1,986,718 $2,048,063 $2,373,593 $43,858,042 CIAC $0 $0 $0 $0 $0 $3,000,000
BEU Funding Cost $2,112,785 $1,820,407 $1,986,718 $2,048,063 $2,373,593 $40,858,042 For the BEU funding cost, 22% is for OH Maintenance Program, 63% is for Capital Maintenance Projects, and 15% is for System-Improvement Projects.
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7.0 – 2026-2045 ESMP SUMMARY

7.1 – Total Overhead Maintenance Program
The Overhead Maintenance Program includes the routine inspection and replacement of poles on the sub-transmission and distribution circuits on the BEU system.

It is projected that BEU will inspect a total of 22,100 poles for the duration of the ESMP. An estimated cost of $278 per pole inspection was used for 2026 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole inspections for the ESMP is $8,501,657.

It is projected that BEU will replace 1,850 for the duration of the ESMP. An estimated cost of $7,746 per pole replacement was used for 2026 and a 3% inflation to this cost was assumed per year every year after thru 2045. The total estimated cost for pole replacements for the ESMP is $19,525,523.

The total estimated cost for the Overhead Maintenance Program for the ESMP is $28,027,180.

7.2 – Total Capital Maintenance Program
BEU has identified 23 Capital Maintenance Projects to include in the ESMP. The total estimated cost for these projects is $29,134,500. It is projected that BEU will receive $12,293,750 in contributions in aid to these projects bringing the total BEU funding cost to $16,840,750.

7.3 – Total Distribution System Improvement Projects
Analysis was run using Milsoft’s Windmil software on the distribution system to determine system improvement projects to correct low voltage, decrease conductor and equipment loading, and reduce single phase line loading to aid in phase balancing. The analysis results include:
• 19 projects to switch load to adjacent lines at a total estimated cost $58,800 • 12 projects for new underground line construction totaling $7,443,500 • 2 projects for new overhead line construction totaling $1,219,000, • 9 projects for single-phase to three-phase line rebuild totaling $2,142,100 • 11 projects for overhead line rebuild using larger conductor totaling $2,212,100 • 4 projects for replacing underground line using larger conductor totaling $1,269,500 The total estimated cost for distribution system improvements is $14,345,000. 7-1
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7.4 – Total 2026-2045 ESMP Cost Estimate
The table below contains a breakdown of the total estimate cost for the 2026-2045 ESMP. 2026-2045 Electric Service Master Plan
5-year CIP 15- Year ESMP Totals
OH Maintenance Program
Total Cost $4,058,438 $23,968,742 $28,027,180
CIAC $0 $0 $0
BEU Funding Cost $4,058,438 $23,968,742 $28,027,180
Capital Maintenance. Projects
Total Cost $20,784,500 $8,350,000 $29,134,500
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $11,490,750 $5,350,000 $16,840,750
System Improvement Projects
Total Cost $2,805,700 $11,539,300 $14,345,000
CIAC $0 $0 $0
BEU Funding Cost $2,805,700 $11,539,300 $14,345,000
Total ESMP Cost
Total Cost $27,648,638 $43,858,042 $71,506,680
CIAC $9,293,750 $3,000,000 $12,293,750
BEU Funding Cost $18,354,888 $40,858,042 $59,212,930
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