Agenda packet — Colton City Council, May 6, 2025 (part 1 of 2)

1 CITY OF COLTON
City Hall, Council Chambers
650 N. La Cadena Drive
Colton, CA 92324
Website: www.coltonca.gov

Mayor Frank J. Navarro
Council Members:

David J. Toro – District 1
Kelly J. Chastain – District 2
Dr. Luis S. Gonzalez – District 3
John R. Echevarria – District 4

City Clerk Isaac T. Suchil
City Treasurer Henry M. Razo

City Manager William R. Smith
City Attorney Carlos Campos

AGENDA

CITY COUNCIL,

COLTON UTILITY AUTHORITY, COLTON PUBLIC FINANCING AUTHORITY,

COLTON HOUSING AUTHORITY

REGULAR MEETING
TUESDAY, MAY 6, 2025 – 5:00 P.M.

CITY HALL, COUNCIL CHAMBERS
CLOSED SESSION - 5:00 p.m.

CLOSED SESSION CALLED TO ORDER

ROLL CALL
PUBLIC COMMENT - Closed Session
This is the portion of the meeting specifically set aside to invite your comments regarding Closed Session items and other general comments about matters not on the agenda; however, any matter that requires action will be referred to staff for investigation and report at a subsequent Council meeting. The Council is prohibited by law from discussing or taking immediate action on items during this public comment period.

Persons desiring to submit paperwork to the City Council Members shall provide a copy of any paperwork to the City Clerk for the Official Record.

Speakers will be limited to 3 minutes; provided, however, that the presiding officer shall have certain discretion to extend or limit time as provided for in the City Council Manual of Procedure.

Please state your name and your City of Residence before providing your comment.

2 A. CONFERENCE WITH LABOR NEGOTIATORS
Pursuant to Government Code Section 54957.6
Agency Designated Representatives: Bill Smith, City Manager Employee Groups: Teamsters - General Employees
Teamsters - Mid-Manager Employee Association
International Brotherhood of Electric Workers, Local 47 - Electric Division International Brotherhood of Electric Workers, Local 47 - Water/Wastewater Division Colton Police Officers Association (CPOA)
Colton Police Management Association (CPMA)
Colton Police Dispatchers Association (CPDA)
Colton Police Civilian Employee Association (CPCA)
Colton Firefighters Association (CFA)
Confidential Employees Group
B. CLOSED SESSION - CITY ATTORNEY EVALUATION
Public Employee Evaluation
Title: City Attorney

CITY ATTORNEY ORAL REPORT ON CLOSED SESSION ACTIONS

RULES OF DECORUM

To help conduct the business of the City Council in an orderly fashion, the City Council has adopted rules pertaining to decorum and order, as provided for in the City Council Manual of Procedure. The City Council will strictly enforce these rules in order to allow full expression of ideas and opinions by councilmembers, staff and the public. Generally, the City's rules of decorum prohibit comments or actions which willfully disrupt the meeting. All remarks and questions shall be addressed to the Council as a whole and not to any particular member. No individual Councilmember or member of the City staff shall be questioned without first obtaining permission from the Presiding Officer. The City Council asks that all persons - including councilmembers, staff and the public - act and speak respectfully.

OPEN SESSION
6:00 P.M.

OPEN SESSION CALLED TO ORDER
INVOCATION Pastor Peter Tasaka - The Vineyard
FLAG SALUTE Veterans of Foreign Wars (VFW) Commander Bernie Moyeda

ROLL CALL

CEREMONIAL MATTERS
Presentations, Awards, Proclamations
• Proclamation - Colton Area Museum Day
• Proclamation - Professional Municipal Clerks Week 2025 • Recognition - Hometown Heroes Program: New Military Banner Installation

3 MAYOR AND COUNCIL ITEMS

GIFT DISCLOSURES
Prior to rendering a decision in any proceeding involving a license, permit, contract or other entitlement pending before the City Council, any Council Member who has received been promised a gift or gifts aggregating $50.00 or more in value within the preceding twelve months from a party or participant in the proceeding shall disclose that fact either orally or in writing during open session. This disclosure shall be made part of the official public record of the proceeding, either as part of the minutes of the meeting or as a separate writing filed with the city. (CMC Section 2.04.030) AB 1234 ORAL REPORTS
Members of the City Council shall provide brief reports on meetings attended at the expense of the city. (GC Section 53232.3(d))

APPOINTMENTS
• Appointment - RIX JPA - Appointment of Public Works Director & Utilities Director Chad Blais as Alternate Member to RIX JPA

MAYOR AND COUNCIL DISCUSSION ITEMS

PUBLIC HEARINGS

To speak on public hearing items, it is requested that you obtain a card from the City Clerk and complete it by noting the agenda item number, as well as whether you are in favor, opposition or neither, and give it to the City Clerk. The applicant will be allowed 5 minutes to address the Council and all other persons will be allowed 3 minutes; provided, however, that the presiding officer shall have certain discretion to extend or limit time as provided for in the City Council Manual of Procedure.

(1) Assembly Bill 2561 Vacancy Report - TIME AND PLACE FIXED TO CONSIDER A PUBLIC HEARING FOR ASSEMBLY BILL 2561 VACANCY REPORT AND PUBLIC HEARING.
[Staff Person: Tom Cody]
Mayor announces the Public Hearing Open.

City Clerk submits the Affidavit of Publication and reports on protests or objections thereto.

Staff Presentation.

Public Comment.

After hearing public comment, on motion by Councilmember _________, seconded by Councilmember _________, the Public Hearing is terminated.

MOTION __________ SECOND __________

4 (2) Public Hearing - Electric Rate Adjustments - TIME AND PLACE FIXED TO CONSIDER A PUBLIC HEARING TO APPROVE AND ADOPT A RESOLUTION TO APPROVE ELECTRIC RATE ADJUSTMENTS, RESOLUTION NO. R-28-

25. [Staff Person: Charles Berry]
Mayor announces the Public Hearing Open.

City Clerk submits the Affidavit of Publication and reports on protests or objections thereto.

Staff Presentation.

Public Comment.

After hearing public comment, on motion by Councilmember _________, seconded by Councilmember _________, the Public Hearing is terminated.

MOTION __________ SECOND __________

BUSINESS ITEMS
There are no Business Items.

PUBLIC COMMENT Limit 3 Minutes
This is the portion of the meeting specifically set aside to invite your comments regarding Closed Session items and other general comments about matters not on the agenda; however, any matter that requires action will be referred to staff for investigation and report at a subsequent Council meeting. The Council is prohibited by law from discussing or taking immediate action on items during this public comment period.

Persons desiring to submit paperwork to the City Council Members shall provide a copy of any paperwork to the City Clerk for the Official Record.

Speakers will be limited to 3 minutes; provided, however, that the presiding officer shall have certain discretion to extend or limit time as provided for in the City Council Manual of Procedure.

Please state your name and your City of Residence before providing your comment.

CONSENT CALENDAR
All matters listed under the Consent Calendar are considered by the City Council to be routine and will all be enacted by one motion. There will be no separate discussion of these items prior to the time the City Council votes on the motion, unless councilmembers, staff or the public request that specific items be discussed and/or removed for separate discussions or action.

(3) Minutes - Approval of Minutes for the City Council Special Joint Meeting Held on April 07, 2025, and the City Council Regular Meeting Held on April 15, 2025, on File in the Office of the City Clerk. [Staff Person: Isaac T. Suchil]
(4) Warrants - Approve voucher numbers 218381 to 218459 dated 03/26/2025 and totaling $98,743.72; voucher numbers 218460 to 218562 dated 03/27/2025 and totaling $1,236,729.41, replacement checks 218563 to 218564 dated 04/01/2025 totaling $6,804.35; voucher numbers 218565 to 218728 dated 04/03/2025 and totaling $1,492,953.27 and voucher numbers 218729 to 218823 dated 04/10/2025 and totaling $3,871,138.61.
[Staff Person: Stacey Dabbs]

5 (5) Agreement - Southern California Public Power Authority - Enter Into the First Amendment to Phase II Renewable Development Agreement with Southern California Public Power Authority (SCPPA) for Renewable Energy Development Projects.
[Staff Person: Charles Berry]
(6) Change Order - Roadway Engineering & Construction Corp. - Approve of Change Order No. 1 for the Police Department Parking Lot Expansion Project with Roadway Engineering & Construction Corp. [Staff Person: Anthony Vega]
(7) Contract Amendment - Ninyo & Moore - Approve Contract Amendment No. 4 with Ninyo & Moore to Complete Environmental Work at Corporate Yard.
[Staff Person: Charles Berry]
(8) Contract Award - Innovative Playground Design - Award Contract to Innovative Playground Design for Installation of Cooley Ranch State Preschool Playground. [Staff Person: Deb Farrar]
(9) Emergency Condition - Agua Mansa Power Plant - Confirm Ongoing Emergency Condition at Agua Mansa Power Plant.
[Staff Person: Charles Berry]
(10) Project List - Road Repair and Accountability Act of 2017 (SB-1) - Approve and Adopt a Resolution to Approve List of Project for Fiscal Year 2025/2026 Road Repair and Accountability Act of 2017 (SB -1), RESOLUTION NO. R-27-25.
[Staff Person: Chad Blais]
(11) Purchase - American Power Systems, LLC - Approve Purchase of 130VDC Battery Bank and Charger from American Power Systems, LLC.
[Staff Person: Charles Berry]
(12) Purchase - Inner-Tite - Approve Purchase of Electric Meter Lock Rings from Inner-Tite. [Staff Person: Charles Berry]
(13) Second Reading of Ordinance O-04-25 & O-05-25 - Approve Second Reading of an Ordinance of the City Council of the City of Colton, California Amending Title 13, Section 13.04 of the Colton Municipal Code Establishing Water Capacity Charges & an Ordinance Amending Title 13, Section 13.16 of the Colton Municipal Code Establishing Wastewater Capacity Charges, ORDINANCE O-04-25 & O-05-25. [Staff Person: Stephanie M. Vargas]
(14) Set Public Hearing - Cal Fire Hazard Severity Zones (FHSZ) - Set Public Hearing for May 20, 2025 to Approve ORDINANCE NO. O-06-25 Adopting LRA Fire Hazard Severity Zones. [Staff Person: Ray Bruno]

MAYOR AND COUNCIL ORAL REPORTS AND COMMENTS
Comments from Mayor and Council on various issues and activities throughout the community. Comments shall be limited to 5 Minutes per speaker.

CITY MANAGER'S REPORTS

ADJOURNMENT

6 I, Stephanie M. Vargas, the Chief Deputy City Clerk, hereby certify that a true and correct, accurate copy of the foregoing agenda was posted, at least seventy-two (72) hours prior to the meeting per Government Code 54954(a), at the following locations:

City of Colton City Hall 650 N. La Cadena Drive
City of Colton Website, www.coltonca.gov <http://www.coltonca.gov>

PROCEDURES FOR ADDRESSING CITY COUNCIL

For the Official Record, it is requested that you obtain a card from the Deputy City Clerk and complete it by noting a specific item number on the Agenda, if applicable, or you can identify the subject that you wish to address under the Public Comment portion of the Agenda. The City Council encourages public input on all City issues within the Rules of Decorum. Speakers will be limited to the time periods provided on the Agenda; provided, however, that the presiding officer shall have certain discretion to extend or limit time as provided for in the City Council Manual of Procedure.

RULES OF DECORUM

NOTICE TO PUBLIC

Staff reports or other written documentation relating to each item referred to, on the Agenda, are available for public inspection at the following locations: Office of the City Clerk, 650 N. La Cadena Drive, Colton, CA; City of Colton Public Library, 656 9 th St., Colton, CA; or the City of Colton Internet Website, www.coltonca.gov. Any person having questions concerning any item on the Agenda may call the City Clerk at 370 -5191 to make inquiry concerning the nature of the item described on the Agenda. The City Clerk shall direct inquiries to the appropriate office.

All matters listed under the Consent Calendar are considered by the City Council to be routine and will all be enacted by one motion. There will be no separate discussion of these items prior to the time the City Council votes on the motion, unless councilmembers, staff or the public request that specific items be discussed and/or removed for separate discussions or action.

7 In compliance with the American with Disabilities Act, if you need special assistance to participate in a City Meeting, please contact the City Clerk’s Office at 909 -370-5001. Notification 48 hours prior to the meeting will enable the City to make reasonable arrangements to ensure accessibility to this meeting.

LEGAL CHALLENGES

If you challenge in court any discussion or action taken concerning an item on this Agenda, you may be limited to raising only those issues you or someone else raised during the meeting or in written correspondence delivered to the City at or prior to the City's consideration of the item at the meeting.

MANUAL OF PROCEDURE

The City Council adopted its Manual of Procedure pursuant to Resolution No. R-41-18, with the latest updates being approved on November 2, 2021. Copies are available in the Office of the City Clerk.

ITEM NO. 1

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: TOM CODY, HUMAN RESOURCES DIRECTOR
SUBJECT: TIME AND PLACE FIXED TO CONSIDER A PUBLIC HEARING FOR ASSEMBLY BILL 2561 VACANCY REPORT AND PUBLIC
HEARING.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

It is recommended that the City Council consider:

1. Conducting a public hearing to present the status of vacancies, recruitment and retention efforts per Government Code section 3502.3; and

2. This is a report and file business item.

BACKGROUND

On September 22, 2024, Governor Newsom signed Assembly Bill 2561 (“AB 2561”) into law to amend the Meyers -Milias-Brown Act (“MMBA”) and create a new obligation for public agencies to address the status of their vacancies publicly.

Effective January 1, 2025, Government Code Section 3502.3 requires public agencies to hold at least one public hearing per fiscal year to discuss the City's workforce vacancies and recruitment and retention efforts. The City's recognized employee associations are provided with a dvance notice of the public hearing.

In compliance with the new legal obligation under AB 2561, public agencies must present the status of their vacancies in a public hearing before their governing body at least once per fiscal

1.1 Packet Pg. 8
Staff Report to the Mayor and City Council
Assembly Bill 2561 Vacancy Report
May 6, 2025

Page 2 ends

year. The presentation must be made before the adoption of a final budget for the fiscal year.

The City's recognized employee associations may present concerning vacancies, recruitment, and retention efforts during the public hearing . The City has nine bargaining units and two unrepresented groups . Additional reporting obligations would occur if vacancies within a single bargaining unit meet or exceed 20% of the full-time total number of authorized positions, at the affected bargaining unit's request.

ISSUES/ANALYSIS

The vacancy rate for any bargaining unit that meet or exceeds 20% of the authorized full -time positions in the bargaining unit, upon request of the recognized employee organization for that bargaining unit, the City must provide additional information during the public hearing, including the follow: 1) The total number of vacancies; 2) The number of applicants; 3) The average time to fill position(s); and 4) Opportunities to improve compensation and working conditions for employees in the bargaining unit. The Vacancy Report for each association/unit is attached.

The City has taken steps to address recruitment efforts in recent years. The City of Colton competes with the agencies in the regional communities from a limited pool of qualified candidates, and this competition, combined with Colton occupying the lower end of the regional pay scale, resulted in a recruitment and retention emergency for the City. The City could not attract qualified candidates or retain existing City employees for multiple layers of every City Department, and this was especially true for the City’s Public Safety Departments.

Upon this recognition, the City Manager's Office and the City Council have taken decisive and aggressive action to address this issue over the past few years. First, to address this for safety personnel, in March 2022, the City Council approved hiring bonuses for newly hired Safety Personnel within the Police and Fire departments. In July 2023, the City Council approved a 10% salary increase for all full -time City employees. In the Spring/Summer of 2024, the City Manager initiated a strategic Labor Plan to bring Colton staff up to the 50th percentile of the regional labor market. This labor -intensive process included reviewing agency salary information and current and future MOUs for comparable agencies. The approved 3-tier system addresses below -average salaries by employee groups, and two of the three tiers were implemented in July 2024 and February 2025. The last tier was just approved on April 15, 2025.

The Labor Plan was a cooperative and transparent process with each of the nine Employee Group Associations. City staff met with each group and shared data, so the City and the Associations agreed on the proper classification of MOU-identified comparable agencies.

The efforts of this City Council to address recruitment and retention have been unprecedented.

These in-contract adjustments to bring Colton up to regional competitiveness have borne fruit; the numbers and quality of applicants have increased, no -shows to interviews have declined, and our vacancy numbers, although some still exist, have significantly improved.

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Staff Report to the Mayor and City Council
Assembly Bill 2561 Vacancy Report
May 6, 2025

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Moving forward, staff will track and report additional recruitment details and data related to the regulations of the new Government Code.

FISCAL IMPACTS

No identifiable fiscal impacts are associated with conducting the public hearing as required under Government Code section 3205.3. However, potential fiscal impacts to address recruitment and retention issues for future budget and bargaining considerations will be presented to the City Council if needed.

ALTERNATIVES

1. Provide alternative directions to staff.

ATTACHMENT

1. Vacancy Report as of April 15, 2025

ATTACHMENT

1. Vacancy Report as of 4-15-25

1.1 Packet Pg. 10
Vacancy Information - Bargaining Units
Bargaining Units at or exceeding 20% vacancy rate identified in Red % Unit
# of
Vacancies
# of Filled
Positions
# of Budgeted
FTEs
% of
Vacancies
Teamsters General Unit 9 69 78 11.54%
Teamsters Mid-Manager Unit 5 48 53 9.43%
Colton Police Civilian Employee Association 3 16 19 15.79% Colton Police Officer Association 5 54 59 8.47%
Colton Police Dispatchers Association 0 12 12 0.00%
Colton Police Management Association 1 2 3 33.33%
Colton Fire Fighters Association 4 42 46 8.70%
International Brotherhood of Electric Workers - Electric Unit 5 30 35 14.29% International Brotherhood of Electric Workers - Water/Wastewater 7 30 37 18.92% Unrepresented (Confidential & Executive) 0 22 22 0.00%
Total 39 325 364 10.71%

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Packet Pg. 11
Attachment: Vacancy Report as of 4-15-25 (4900 : Assembly Bill 2561 Vacancy Report)

ITEM NO. 2

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHARLES BERRY, ELECTRIC UTILITY DIRECTOR
SUBJECT: TIME AND PLACE FIXED TO CONSIDER A PUBLIC HEARING TO

APPROVE AND ADOPT A RESOLUTION TO APPROVE ELECTRIC
RATE ADJUSTMENTS, RESOLUTION NO. R-28-25.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Hold Public Hearing for the Colton City Council Meeting of May 6, 2025, to Consider Adoption of Electric Rate Adjustments, Resolution NO. R-28-25.

BACKGROUND

City of Colton Electric Utility (CEU) operates an electrical grid to provide service to more than 18,000 electric meters within the City’s service territory across multiple rate classes . It is considered prudent industry practice to perform regular cost -of-service studies to align expenses and revenue requirements with cost causation. As such, the City Council awarded a Professional Services Agreement to EES Consulting on June 7, 2022, at its regular meeting. A subsequent amendment was approved to extend the term of the Agreement through June 30, 2024 to perform further cost analysis due to fluctuations in market conditions. A third amendment to the Agreement was approved by Colton City Council on June 18, 2024, amending the terms and conditions to provide ongoing analysis, report finalization and presentation of recommendations.

The study findings were presented in public forum at a Special Council meeting on February 24, 2025, the regular Utilities Commission on March 10, 2025, a joint Council -Commission workshop on April 7, 2025, and again at the regular Utilities Commission on April 14, 2025.

Each event resulted in robust discussion, generating follow -on questions from stakeholders, of which staff provided responses and sought ongoing feedback and direction from Council.

1.2 Packet Pg. 12
Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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At the publicly attended meetings, EES Consulting and City Staff , acting as fiduciaries , presented findings with recommended rate level adjustments and forward -looking revenue requirements to continue to provide reliable, stable, predictable rates that are competitive and support the maintenance , operations and ongoing investments need for a safe electric grid and mindful of ongoing Council priorities.

ISSUES/ANALYSIS

Since 2009, the last year electric rates were increased, CEU rates have remained steady and were subsequently reduced in 2011 and again in 2013. Since 20 09, inflation has increased more than 50 percent and CEU’s cost to provide service to its customers has increased, yet rates were held flat. The convergence of these facts further necessitat ed a thorough rate study that did not overreact to volatile energy markets yet was representative of current and future costs, causation of costs and demonstrated compliance with Proposition 26.

Study results and recommendations, which are tied to rate -class cost causation, illustrate the prudent financial management which makes adjustments to rates that are : reflective of the current cost for providing service ; including reducing tiered rates where appropriate in a cost - neutral way for simplicity and efficiency ; adjusting the time -of-use (TOU) schedule to reflect market signals ; adjust the fixed charge ; update reserve policy; and, adjust the Public Benefits charge to comply with statutory requirements.

The rate recommendations result in projected revenue adjustments of three percent in Fiscal Year 2026, two percent in Fiscal Year 2027, two percent in Fiscal Year 2028 and one percent in Fiscal Year 2029, respectively. These revenue adjustments and bill impacts have an opportunity for mitigation as a result of more robustly funding income-driven assistance programs , including a new income -qualified senior citizen program providing a 37 percent on bill discount, a 25 percent on bill discount for all other income-qualified customers, which will replace the existing low-income program , along with energy efficiency and conservation measures available to residential, commercial and industrial customers . These programs provide direct assistance to customers in the form of on-bill discounts, direct install programs and other subsidized efficiency options that result in immediate relief as well as on -going and future savings . The results of enhancing these efforts will insulate the most vulnerable households to the extent practicable from rate adjustments while also programming funding to continue to support commercial and industrial customers.

The average residential user will see an increase of approximately $0.54 per-month during the remainder of Fiscal Year 2026 upon implementation (October – June, 2026), and $7 per-month in Fiscal Year 202 7, the first full year of implementation. In Fiscal Year 2028, the project residential bill impact is approximately $5 per -month and in Fiscal Year 2029 it is projected at $3 per-month, resulting in an aggregate increase of approximately $15 per month over the course of the next four fiscal years. Electric rate adjustments, if implemented as recommended, will

1.2 Packet Pg. 13
Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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continue to maintain an approximate 40 percent discount when compared to the typical investor- owned utility for the average residential customer and a nearly 30 percent discount compared to the statewide average. The proposed residential rate level is represented in the following table.

Commercial and Industrial customers will also experience adjustments on their respective bill, with some realizing minor adjustments that may result in decreases, while others may see slight increases, depending upon the preponderance of consumption characteristics. The following charts summarize the rate adjustment recommendations for those respective rate classes.

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Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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Additionally, the following chart illustrates recommended rate adjustments to lighting rates, which include customers who choose to have CEU maintain unmetered lig hts for purposes such as area lighting, parking lot lighting or other general uses.

Staff, also at the request of the Council, evaluated debt funding for ongoing maintenance operations. However, this was later evaluated as sub-optimal by the City’s Financial Advisor and determined to be in conflict with approved City Financial Policy. Although further investigation at the time suggested refinancing of existing 2007A & 2012A bonds as means to fund additional ongoing maintenance was practical, it would not have a material impact on rate adjustment recommendations.

At the time of initial investigation into bond refinancing, market conditions were favorable, that however has been challenged in recent days. Staff continues to monitor the market and evaluate other scenarios to minimize debt service pursuant to Financial Policy to minimize upward operating cost pressures. Any such recommendations regarding debt issuance or refinancing of existing debt will be brought forward for City Council consideration at a future date.

In addition to the rate adjustments currently under consideration, Council directed staff to develop a policy regarding rate studies. As such, staff have proposed a policy that establishes

1.2 Packet Pg. 17
Staff Report to the Mayor and City Council
Public Hearing - Electric Rate Adjustments
May 6, 2025

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roles and responsibilities, timelines for regular and targeted studies in addition to outline general frameworks to be consistent with industry best practices. This document is attached to the Resolution R-28-25 as Exhibit “B”.

Last, staff presented for Council consideration an update to the City’s Reserve Policy that would increase Working Capital Reserve (liquidity) to 25 percent operating cash and 25 percent rate stabilization while adjusting the net-position reserve requirement to a minimum of 25 percent by Fiscal Year 2028 -2029. After that time, the minimum net -position will adjust upwards to 50 percent.

FISCAL IMPACTS

Rate adjustment adoption, Fiscal P olicy adoption and Rate Study Policy adoption, will provide the following 1) increase revenues to cover increasing operations and maintenance costs , 2) enable the enterprise to continue to service debt, meet its coverage ratios and bond covenants, 3) increase reserve policy to maintain financial stability in line with prudent best industry practices, 4) provide needed funding to mitigate fluctuations in operating costs, 5) provide predictable and stable rates into the future 6) continue to support ongoing system maintenance needs and 7) establish policy regarding rate studies.

As recommended, rate implementation would occur in October 2025 and future adjustments would occur July 1 of each fiscal year thereafter.

ALTERNATIVES

Provide alternative direction to staff.

ATTACHMENT

1. Rate Study Policy_cjb_04082025_V3.0 2025.04.17 BBK Edits-c1

2. City of Colton Financial Policies_20170801_cjb_V1.0

3. Colton Electric COSA Report Draft 4.4.25

4. Colton - Resolution Increasing Electric Rates (2025) and Adopting Various Policies-c1 (002)

1.2 Packet Pg. 18
Exhibit B
Policy on Conducting Electric Rate Studies

1. Purpose The purpose of this Policy on Conducting Electric Rate Studies (Policy) is to establish a structured approach for conducting electric rate studies to ensure fair, transparent, and cost-effective electricity pricing for City of Colton (City) customers while maintaining the financial stability of the City’s Electric Utility, supporting City Council priorities, and complying with State legal and regulatory requirements. Electric rate studies (Study or Studies) help identify equitable pricing structures, optimize operational efficiency, ensure legal and regulatory compliance, and anticipate market trends. By implementing a standardized process, the utility can adapt to changing economic conditions, energy demands, and sustainability goals. A standardized process will promote long-term system reliability and consumer satisfaction and will help ensure fiduciary responsibility for managing the City’s assets.

2. Scope This Policy applies to all electric rate studies conducted by or on behalf of the City’s Electric Utility, including periodic reviews, special studies, and rate adjustment assessments. Studies conducted pursuant to this Policy shall consider all customer classes, including but not limited to, residential, commercial, and industrial, to ensure a balanced, data-driven approach that reflects usage patterns and infrastructure requirements. Studies shall also address emerging trends in renewable energy adoption, fuel-switching, electrification, energy efficiency measures, and grid modernization efforts to align with industry developments and state mandates.

3. Responsibilities
• The City Council shall have sole authority to adopt Study recommendations and approve any rate adjustments.
• The Electric Utility shall supply technical data, including, but not limited to consumption data, financial information, system demand, infrastructure costs, grid performance, and capacity planning considerations.
• The Finance Department shall ensure alignment with financial policies, including reserve and debt coverage requirements.
• External consultants may be engaged as necessary to provide expert analysis, model various pricing scenarios, and ensure that the Study incorporates industry best practices and innovations in rate structuring.
• Customer input will be solicited through regular and special City Council and Utilities Commission meetings.

4. Frequency of Studies

1.2.a
Packet Pg. 19
Attachment: Rate Study Policy_cjb_04082025_V3.0 2025.04.17 BBK Edits-c1 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit B
• A comprehensive Study shall be conducted at least once every five years to reassess utility costs, revenue requirements, financial policy compliance, and economic conditions.
• Interim Studies may be performed as needed in response to significant economic, regulatory, or operational changes, such as inflationary pressures, fuel cost fluctuations, or infrastructure investment requirements. • Additional targeted Studies may be conducted when significant policy shifts occur, such as mandates for renewable energy integration, electrification of transportation, or significant changes in consumer demand patterns.

5. Key Components of an Electric Rate Study
• Cost of Service Analysis (COSA): A detailed assessment of the cost to provide electricity to different customer classes, ensuring that rates reflect actual usage and service costs in a fair and equitable manner.
• Revenue Requirement Analysis: Calculation of the total revenue required to cover operational costs, capital investments, regulatory compliance costs, reserve requirements, and long-term system maintenance to ensure financial sustainability. • Rate Design Analysis: Development of rate structures that align with cost allocation requirements while considering factors such as price competitiveness, cost allocation, and cost-causation.
• Impact Analysis: Evaluation of how proposed rate changes affect different customer classes, including economic impact assessments and mitigation strategies for economically vulnerable customers.
• Regulatory Compliance: Ensuring that rate structures comply with all applicable local, state, and federal laws and regulations, as well as industry standards for rate- setting transparency and fairness. Each Study shall provide the City Council with a document of record in support of retail rate compliance with Article XIII C of the Constitution of the State of California (Proposition 26). • Alternative Rate Models: Where feasible, explore new and emerging trends in industry.
• Risk Analysis: Evaluate potential risk to the Electric Utility to include o Operational Risk: Equipment failures, power outages, and cyber threats. o Market Risk: Fluctuations in market prices and demand shifts.

1.2.a
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Attachment: Rate Study Policy_cjb_04082025_V3.0 2025.04.17 BBK Edits-c1 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit B
o Environmental Risk: Extreme weather events and climate adaptation. o Financial Risk: Credit risks, rate recovery challenges, market exposure, and power supply considerations.

6. Public Participation and Transparency
• Public input shall be solicited through City Council-facilitated workshops, Utilities Commission workshops, special meetings, and rate hearings. • Study results and proposed rate changes shall be made publicly available through utility websites, public forums, and official reports prior to implementation to ensure transparency and accountability.
• Consumer education initiatives shall be implemented to help customers understand the rationale behind rate adjustments, as well as available assistance programs for low-income households.

7. Approval and Implementation
• All proposed rate adjustments must be reviewed and approved by the City Council to ensure alignment with legal, financial, and policy objectives. • Implementation of new rates shall be communicated clearly to consumers through multiple channels, including direct notifications, public forums, and media outreach.
• A transition plan shall be defined when rate changes are significant, ensuring that consumers have adequate time to adjust to new pricing structures and that any necessary assistance programs are in place to support economically vulnerable customers.

8. Review and Amendments
• This Policy shall be reviewed periodically and updated as needed to reflect best practices, legal and regulatory changes, technological advancements, and evolving utility operational needs.
• Any amendments to this Policy shall be subject to approval by the City Council. • Ongoing monitoring of energy market trends, technological innovations, and customer behavior shall inform future Policy amendments to ensure that the Study process remains relevant and effective.

1.2.a
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Attachment: Rate Study Policy_cjb_04082025_V3.0 2025.04.17 BBK Edits-c1 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit C

CITY OF COLTON FINANCIAL POLICIES

I. The City will maintain an operating/cash flow General Fund reserve equivalent to a minimum of 15% of the General Fund’s operating budget.

II. The City will maintain a balanced operating budget for al l funds with recurring revenues equal to or greater than recurring expenditures. Appropriations of available fund balance may be permitted for “one -time” non-recurring expenditures. The City Manager will present the proposed budget to City Council prior to June 30 each year.

III. The City will set and maintain enterprise rates in order to provide sufficient revenues (customer charges, interest income, and all other income) to meet all operating expenses, cash reserves per financial policies, and debt service coverage requirements set forth in any applicable bond covenants.

IV. The City will maintain a cash working capital reserve for each Enterprise fund as follows:
• Electric: 25% operating reserve; 25% rate stabilization reserve ; net-position reserve target of 25% by Fiscal Year 2029 with an ultimate net -position reserve requirement of 50%.
• Water: 10% operating reserve
• Wastewater: 10% operating reserve

V. The City will maintain appropriate reserves in the Insurance Fund to meet statutory requirements and actuarially projected needs for General Liability and Worker’s Compensation.

VI. The City will comply with all the requirements of “Generally Accepted Accounting Principles” along with all laws and regulations related to financial reporting and the maintenance of the books and records.

VII. An investment policy shall be updated and ratified in accordance with state law, and the City Treasurer shall be responsible to take this document forward on an annual basis for ratification by the City Council.

VIII. A debt policy shall be maintained and updated as necessary.

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Attachment: City of Colton Financial Policies_20170801_cjb_V1.0 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit C

-I-
The City will maintain an operating/cash flow General Fund reserve balance equivalent to a minimum of 10% of the General Fund’s operating budget.

Maintaining reserves is considered a prudent management practice . Typically, reserves are to be utilized to fund unforeseen situations. Examples include:
• Federal/State/County budget cut;
• Local revenue shortfall due to major business closures or relocations; • Legislative or judicial mandate to provide a new or expanded service or programs; • One-time City Council approved expenditure;
• Natural disaster (earthquake, flood, etc.)
In an effort to ensure sound financial management of public resources, the City Council directs the City Manager to maintain a minimum 10% General Fund reserve amount (defined as an operating/cash flow reserve). The 10% reserve amount applie s to the General Fund’s recurring operating budget only. One-time (non-recurring) expenditures would not be used to calculate the 10% reserve amount.

If unforeseen circumstances occur which cause the reserves to drop below the Council adopted level, staff will immediately present the City Council with various options for curing the deficiency(ies).
-II-
The City will maintain a balanced operating budget for all funds with recurring revenues equal to or greater than recurring expenditures. Appropriations of available fund balance may be permitted for “one -time” non -recurring expenditures. The City Manager will present the proposed budget to City Council prior to June 30 each year.

General Fund
This policy requires that in any given fiscal year the City will not budget appropriations in excess of the estimated revenue expected to be received in the same year except as provided in Section I above. This “pay as you go” approach mandates that any increase in expenditures, decrease in revenues, or combination of the two that would result in a budget imbalance will require cost cutting and/or revenue enhancements, rather than spending unappropriated fund balance (i.e., reserves) to support ongoing operations. Cost cutting measures may include reductions in capital improvement projects or other purchases, reductions in staff (either through attrit ion, hiring freezes, or lay-offs), or reductions in expenditures for materials, services, and supplies.

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Revenue enhancements would generally be in the form of new or increased taxes and fees. Any year-end operating “surpluses” will revert to unappropriated fund balances for use in maintaining reserve levels set by this policy.
-III-
The City will set and maintain enterprise rates in order to provide sufficient revenues (customer charges, interest income, and all other income) to meet all operating expenses , cash reserves per financial policies, and debt service coverage requirements set forth in any applicable bond covenants.

The City’s Enterprise Funds (electric, water and wastewater) will be supported solely by revenue derived from the enterprise’s operations and its interest earned on cash deposits and investments.

None of these funds will be supported or subsidized by the City’s General Fund. However, each Enterprise Fund will be required to reimburse the General Fund and/or other applicable funds, for the full cost of general government support services provided to the Enterprise Fund (such as computer support, accounting, and general administration).

The City shall review rates related to each enterprise on a periodic basis to ensure proper revenue levels are maintained.
-IV-
The City will maintain a cash working capital reserve for each Enterprise fund as follows:
• Electric: 25% operating reserve; 25% rate stabilization reserve; net-position reserve target of 25% by Fiscal Year 2029 with an ultimate net-position reserve requirement of 50%.
• Water: 10% operating reserve
• Wastewater: 10% operating reserve
Each Enterprise Fund will maintain a 10% “working capital” reserve which is sufficient to provide enough funds to allow the City Council to react and adopt a financial plan which can adequately deal with a variety of adverse economic circumstances which may materialize.

Due to unforeseen circumstances, if the working capital reserves drop below levels adopted by this policy, staff will present the City Council with various options for curing the deficiency (ies).

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Attachment: City of Colton Financial Policies_20170801_cjb_V1.0 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit C
-V-
The City will maintain appropriate reserves in the Insurance Fund to meet statutory requirements and actuarially projected needs for General Liability and Worker’s Compensation.

The General Liability and Workers’ Compensation Insurance Fund reserves are to be maintained in a sufficient manner to meet membership requirements for ICRMA (Independent Cities Risk Management Association) and meet our statutory requirements for Workers’ Compensation.

The City must maintain sufficient cash reserves to meet the demands of the self-insured retention levels as required by ICRMA and the State . If the reserves drop below levels prescribed by this policy and cannot be readily replenished through increased user rates, staff will bring the matter to the City Council’s attention and present options.
-VI-
The City will comply with all the requirements of “Generally Accepted Accounting Principles” along with all laws and regulations related to financial reporting and the maintenance of the books and records.

The City will conduct its financial affairs appropriately and maintain records in accordance with Generally Accepted Accounting Principles as established by the Governmental Accounting Standards Board. In addition, all applicable laws and regulations related to financial reporting and the maintenance of the books and records shall be complied with. This pertains to the timely and accurate filing of annual financial reports as required by the State Controller’s office. To help assure compliance with this policy, the City must have an annual audit by an independent certified public accounting firm.
-VII-
An investment policy shall be updated and ratified in accordance with state law, and the City Treasurer shall be responsible to take this document forward on an annual basis for ratification by the City Council.

An investment policy is required per the California Government Code which calls for an annual review by the City Council of such policy and related practices, as reported by the City Treasurer. -VIII-
A debt policy shall be maintained and updated as necessary.

Debt is a complex matter for cities and any mismanagement of the debt process (both during and after the issuance of debt) can result in adverse fiscal consequences. Because there are many

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Attachment: City of Colton Financial Policies_20170801_cjb_V1.0 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit C
elements associated with a sound debt policy, it is prudent to incorporate those principles in some degree of detail.

1. The City will not use long-term debt to finance current operations. Long-term borrowing will be confined to capital improvements or similar projects with an extended life which cannot be financed from current revenues.

2. Debt payments shall not extend beyond the estimated useful life of the project being financed. The City will try to keep the average maturity of bonded debt at or below 20 years.

3. The City will maintain good communications with bond rating agencies concerning its financial condition.

4. The City may utilize lease purchasing with specific approval of the City Manager. The useful life of the item must be equal to or greater than the length of the lease. A lease purchase will require City Council approval beyond a five-year lease term or principal amount over the City Manager’s contract authorization level.

5. The City will not obligate the General Fund to secure financing unless the marketability of the issue will be significantly enhanced and a dedicated revenue source for repayment is identified.

6. An analysis shall be prepared for each request for long-term financing which considers the impact on current and future fiscal year budgets for debt service and operations. The analysis shall also address the reliability of revenues supporting annual debt service.

7. The City shall enter into financing contracts on a competitive basis unless, for reasons of market volatility, the use of an unusual financing structure or a complex structure indicates the negotiated financing is preferred.

8. The City will monitor all forms of debt on an annual basis and report concerns or suggested restructuring, if any, to the City Council as part of the budget process.

9. Enterprise and Property owner based financing will only be issued under the assumption that the issue is self-supporting from user fees and charges, assessments and special taxes without impacting the General Fund.

10. The City’s minimum acceptable underlying rating objective on any direct debt is “Baa/BBB”. Appropriate credit enhancements, such as insurance or letters of credit, shall be considered for marketing purposes, availability and cost effectiveness.

11. The City shall diligently monitor its compliance with bond covenants and ensure its compliance with federal arbitrage regulations.

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Attachment: City of Colton Financial Policies_20170801_cjb_V1.0 (4908 : Public Hearing - Electric Rate Adjustments) Exhibit C

12. The City may issue interfund loans rather than outside debt instruments. Interfund loans will be permitted only if an analysis of the lending fund indicates excess funds are available, and the use of these funds will not impact the fund’s current ope rations. The average interest rate, as established by the Local Agency Investment Fund’s (LAIF) most recent quarter, will be paid to the lending fund.

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Attachment: City of Colton Financial Policies_20170801_cjb_V1.0 (4908 : Public Hearing - Electric Rate Adjustments) Electric Cost of Service and Rate
Study – Draft Report
April 4, 2025
Colton Electric
Utility
P R E P A R E D B Y G D S A S S O C I A T E S , I N C .

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Attachment: Colton Electric COSA Report Draft 4.4.25 (4908 : Public Hearing - Electric Rate Adjustments)

1850 Parkway Place ◼ Suite 800 ◼ Marietta, GA 30067 ◼ 770-425-8100 ◼ Fax 866 -611-3791 ◼ www.gdsassociates.com G e o r g i a ◼ Te x a s ◼ A l a b a m a ◼ N e w H a m p s h i r e ◼ W i s c o n s i n ◼ F l o r i d a ◼ M a i n e ◼ W a s h i n g t o n ◼ O r e g o n

Amber Gschwend , Director
amber.gschwend @gdsassociates.com

April 4, 2025

Charles Berry
Electric Utility Director
Colton Electric Utilities
150 S. 10th Street
Colton, CA 92324

RE: Electric Cost of Service Study – Draft Report

Dear Mr. Berry:

Attached please find the final report for the 2025-2029 Colton Electric Utility (CEU) Electric Cost of Service Analysis prepared by GDS Associates.

We based the conclusions and recommendations within the report on standard industry practice and accepted rate setting principles. The assumptions are consistent with earlier draft materials provided by GDS but include refinements to power supply and overall revenue assumptions. In addition, the report includes initial rate design recommendations. Incremental steps toward cost -of-service help prepare utilities for future developments and insulate members from over -and under -collection risk for unexpected changes in member loads and demands.

GDS developed the study with the mutual aid of CEU staff, and we appreciate the internal effort to refine the study. The findings, conclusions and recommendations of this report supply the basis for the development of fair and equitable rates for CEU. Thank you for the opportunity to aid CEU in this rate setting process.

Very truly yours,

Amber Gschwend
Director
425-889-2700
[email protected]

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Attachment: Colton Electric COSA Report Draft 4.4.25 (4908 : Public Hearing - Electric Rate Adjustments) COLTON ELECTRIC UTILIT Y Cost of Service and Rate Study – Draft Report prepared by GDS ASSOCIATES INC i

TABLE OF CONTENTS

1 EXECUTIVE SUMMARY ................................................................................................... 3

1.1 Overview of the COSA ........................................................................................................................................ 3

1.2 CEU Revenue Requirement .............................................................................................................................. 3

1.3 Electric Rate Base ................................................................................................................................................. 5

1.4 Major Assumptions of the COSA ................................................................................................................... 5

1.5 Summary of Allocation Results ....................................................................................................................... 6 2 OVERVIEW AND BASIS FOR THE COSA........................................................................ 8

2.1 Overview of the COSA ........................................................................................................................................ 8

2.2 Legal Considerations........................................................................................................................................... 8

2.2.1 California Constitution‐Article XIII C (Proposition 26) ................................ ........................... 9

2.3 CEU Revenue Requirement .............................................................................................................................. 9

2.4 Rate Base .............................................................................................................................................................. 10

2.6 Projected Load Forecast ................................................................................................................................. 11

2.7 Projected Revenues .......................................................................................................................................... 11 3 COST OF SERVICE ANALYSIS ....................................................................................... 12

3.1 COSA Overview and General Principles .................................................................................................... 12

3.2 Major Assumptions of the Cost-Of-Service Analysis ........................................................................... 13

3.3 Functionalization of Costs.............................................................................................................................. 14

3.3.1 Functionalization of Plant Rate Base ................................ ................................ ..................... 15

3.3.2 Functionalization of Revenue Requirement ................................ ................................ ........... 15

3.4 Classification of Costs ...................................................................................................................................... 17

3.4.1 Classification of Generation and Transmission Rate Base ................................ ................... 18

3.4.2 Classification of Distribution Rate Base................................ ................................ ................. 18

3.4.3 Classification of Production/Power Supply Expenses ................................ ........................... 18

3.5 Allocation of Costs ............................................................................................................................................ 19

3.5.1 Demand Allocation Factors ................................ ................................ ................................ ..... 19

3.5.2 Energy Allocation Factors ................................ ................................ ................................ ........ 20

3.5.3 Customer Allocation Factors ................................ ................................ ................................ ... 20

3.5.4 Other Allocation Factors ................................ ................................ ................................ .......... 20

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3.5.5 Allocation of Rate Base................................ ................................ ................................ ............ 20

3.5.6 Allocation of Revenue Requirements ................................ ................................ ...................... 20

3.6 Load Analysis ...................................................................................................................................................... 21 4 COSA RESULTS .............................................................................................................. 23

4.1 Summary of Allocation Results .................................................................................................................... 23 5 RATE DESIGN ................................................................................................................ 25

5.1 Current Rate Design ......................................................................................................................................... 25

5.2 Recommended Rates ....................................................................................................................................... 26

5.2.1 Residential ................................ ................................ ................................ ................................ 26

5.2.2 Small General Service ................................ ................................ ................................ .............. 27

5.2.3 Medium General Service ................................ ................................ ................................ .......... 28

5.2.4 Time-Of-Use Rate Classes ................................ ................................ ................................ ........ 28

5.2.5 Lighting ................................ ................................ ................................ ................................ ..... 33

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1 Executive Summary
Colton Electric Utilities (CEU) retained GDS Associates (GDS), to perform a comprehensive electric cost of service analysis (COSA). The COSA is one of the major inputs used in developing potential rates for CEU.

The COSA takes the revenue requirements for the utility and allocates costs across the various customer classes, with the results used to ensure that proposed rates are fair, equitable and not unduly discriminatory.

1.1 OVERVIEW OF THE COSA
The COSA takes the revenue requirement for the utility and seeks to equitably allocate those costs to the various customer classes of service (i.e., residential, general service , etc.). This analysis provides a determination of the level of revenue responsibility of each class of service and the adjustments required to meet the cost of service.

There are three basic steps to follow in developing a COSA, namely: Functionalization, Classification, and Allocation. Functionalization separates costs into major categories that reflect the utility’s plant investment and different services provided to customers. The primary functional categories are production, transmission, distribution, and general.

Classification determines the portion of the cost that is related to specific cost -causal factors, such as those that are demand -related, energy-related, or customer -related. Production costs are related to supplying power to customers on the system. Finally, allocation of costs to specific customer classes is based on the customer’s contribution to the specific classifier selected. For instance, demand -related costs are allocated to a customer group using that customer group’s contribution to the measurement of system demand, whether coincident peak, non -coincident peak or some variation determined to be appropriate for the cost item. An analysis of customer requirement, loads, and usage characteristics is completed to develop allocation factors reflecting each of the classifiers employed within the COSA. The analysis may include an evaluation of the system design and operations, its accounting and physical asset records, and detailed studies of customer load data.

1.2 CEU REVENUE REQUIREMENT
A revenue requirement analysis compares the overall revenues of the utility to its expenses and determines the indicated overall adjustment to rate levels. The revenue requirement is the starting point of the COSA, with all items in the revenue requiremen t allocating across the various customer classes.

This study evaluated a 4 year period beginning Fiscal Year 2026 (July 1, 2025 through June 30, 2026). CEU’s revenue requirement for FY 2026 is based on the FY 2025 budget. T he FY2025 budget is adjusted based

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on power supply costs as estimated by Southern California Public Power Authority (SCPPA) and 10-year average price level changes (3.8% per year).1
Revenue Requirement study includes projected revenues collected from retail rates. Retail rate revenues are calculated based on current base rates, the continuation of the PCA through September 30, 2025, and projected loads. Revenues and recommended rates for the forecast years are based on setting the Power Cost Adjustment (PCA) to $0 beginning October 1, 2025. The total FY 2026 expenses $96.0 million. The Change in Net Position indicates use of operating reserves to balance year-to-year rate adjustments. The electric revenue requirement to be collected from retail rates is $ 88.5 million (total Expenses less Misc.

Revenues).2
TAB LE 1-1: PROJE CTE D REVEN UE RE QUIREME NT WITH REC OMMEN DE D RATE ADJUSTMEN T FY: 2026 FY: 2027 FY: 2028 FY: 2029
Retail Rate Revenues
Base Rate Revenue1 $53,723,752 $84,008,011 $85,696,740 $87,419,416 PCA Revenue $8,094,473
Incremental Base Rate Adjustment $21,469,767 $1,191,466 $1,215,417 $619,924 Total Rate Revenues $83,287,991 $85,199,477 $86,912,157 $88,039,340 Expenses
Power Supply $48,654,541 $40,367,118 $43,902,140 $47,104,747 Transmission & Distribution $7,507,057 $7,792,326 $8,088,434 $8,395,795 Customer Accounts and Services $401,479 $416,736 $432,572 $449,009 General & Administrative $13,465,065 $13,976,738 $14,507,854 $15,059,152 Capital Improvement Projects $5,370,000 $6,478,000 $4,822,000 $3,640,000 Other Contributions $17,357,859 $17,371,458 $17,371,458 $17,371,458 Interest and Debt Service $3,210,019 $3,331,999 $3,331,999 $3,331,999 Total Expenses $95,966,020 $89,734,374 $92,456,456 $95,352,160 Misc. Revenues $7,497,127 $7,497,127 $7,722,041 $7,953,702 Retail Revenue Requirement $88,468,893 $82,237,246 $84,734,415 $87,398,458

Change in Net Position -$5,180,902 $2,962,231 $2,177,741 $640,883

Annual Rate Increase Each October 1: 3% 2% 2% 1%

1. Base rate revenue based on retail rates from prior year.

1 Average price level changes as measured by the Consumer Price Index for the Los Angeles area. U.S. Bureau of Labor Statistics. Consumer Price Index, Los Angeles Area . Available at: https://www.bls.gov/regions/west/news- release/consumerpriceindex_losangeles.htm
2 Misc. Revenues includes but is not limited to transmission revenue, California Air Resources Board auction proceeds, service fees, rents and other fees, and interest income.

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1.3 ELECTRIC RATE BASE
The accompanying plant rate base associated with the FY 2026 revenue requirement is $47.9 million. The rate base reflects gross plant of $118.8 million, offset by accumulated depreciation and customer contributions. Distribution makes up 59.3% of gross plant, followed by 6% for general plant, and 35% for production. CEU does not own or operate transmission-level plant.

1.4 MAJOR ASSUMPTIONS OF THE COSA
The following provides some of the major assumptions and underlying data used in conducting the COSA for CEU. Customer classes of service refer to the arrangement of customers into groups that reflect common usage characteristics or facility requirements. The classes of service analyzed in the study are summarized in Table 1-2.

TAB LE 1 -2 C OSA CUSTOMER C LASSE S
Size
Average Number of
Accounts FY 2026
Residential Any 16,182
General Service < 20 kW 1,688
Medium General Service 20-200 kW 376
Large General Service (TOU 1 LGS) >200 kW 22
Industrial >200 kW 50
Municipal Any 207
Lighting N/A 124
Total

18,649

CEU is projecting increasing energy sales through the forecast period. Total metered services of 18,6 49 on average for FY 2026 and gross energy consumption of approximately 327,696 MWh.

Residential customers make up 87 percent of the total number of customers and 31 percent of energy sales. In contrast small general Service customers make up only 9 percent of customers and contribute 13 percent of total retail sales. The peak is forecast to occur in the summer at a level of 54 MW and winter at a level of 82MW.

Key data and allocation assumptions include:
◼ Forecast fiscal year (FY) 2026 is the test period for the allocation of costs. ◼ Billing data by rate class for all meters in each rate class from the historical FY 2024 provided the basis for energy and demand allocation factors for the FY 2026 forecast year. ◼ The FY 2026 forecast revenue requirement and sales based on the most recent budget. ◼ Power supply costs classified as demand and energy based the split of fixed and variable operating costs for each resource.

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◼ Distribution plant classified based on estimate of minimum system characteristics for municipal electric distribution assets.
◼ Purchased transmission costs were allocated based on energy to reflect the rate structure of the California Independent System Operator (CAISO).
◼ Resource Adequacy and other transmission purchases are classified and allocated according to the utility’s coincident peak demand.

1.5 SUMMARY OF ALLOCATION RESULTS
Given the above assumptions of the COSA, the various costs were classified and allocated to the customer classes of service. This section supplies the results of the COSA in summary form. The body of the report describes additional detail from the analysis.

In the COSA process, plant investment is classified and allocated to rate classes as a means to allow for proper allocation of those revenue requirements tied to plant investment, such as distribution operations and maintenance and depreciation expenses. P roduction plant is classified and allocated based on demand. Distribution plant classification is split between demand and customer. Customer costs represent the estimated share of plant value needed to serve each customer according to a theoretical 1 kWh/year usage level. The remainder of the plant value is allocated based on customer demands as this is the investment needed to meet individual customer needs. General plant is allocated based on the distribution plant allocations.

The total FY 2026 net revenue requirement of $88.5 million3 is classified into various components and allocated to customer classes. Table 1-2 summarizes the results for fiscal year 2026.

TAB LE 1-2: C OSA RE SULTS : FY 2026

Allocated Revenue
Requirement
Revenues at
Current Rates1
Normalized
Revenue to Cost
Ratio2
Residential $32,925,171 $19,222,059 83%
Small General Service $11,290,864 $9,525,999 121%
Medium General Service $8,104,244 $7,188,149 127%
Industrial $12,267,349 $10,489,960 122%
TOU LGS $22,383,276 $14,467,503 92%
Municipal $589,211 $705,288 171%
Lighting $908,778 $277,214 44%
Total System $88,468,893 $61,876,173 100%

1. Includes PCA revenue through September 2025.

2. Adjusted for 100% recovery of revenue requirement.

3 Expenses less Misc. Revenues.

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The results of the COSA indicate that, at current rate levels, Residential and Lighting classes are under collecting in relationship to the cost to serve each class respectively. The recommended rates adjust the relative rate levels so that the revenue to cost ratios are balanced.

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2 Overview and Basis for the COSA
The COSA is one of the major inputs used in developing proposed rates for CEU. The COSA takes the revenue requirements established for the utility and allocates costs across the various customer classes, with the results used to ensure that proposed rates are fair, equitable and not unduly discriminatory.

GDS organized this report such that it follows the steps taken in analyzing and developing CEU’s COSA.

Contained in this section is a discussion of the theory and financial principles behind setting rates. Also included is a summary of the underlying financial results used as the basis for the COSA. The next section discusses the COSA and the results of that process, including the method used to allocate costs between customer classes. The final section provides a summary of the COSA results.

2.1 OVERVIEW OF THE COSA
The setting of electric utility rates that are fair and equitable is a complex process. But the process follows generally accepted methodologies as a guide for assessing cost recovery in CEU’s electric rates. At the same time, there are often several financial principles or guidelines that must be taken into consideration during this process. Therefore, the setting of electric rates that are fair and equitable is an integration of these generally accepted methodologies and any related financial policies or specific policy considerations from CEU.

The COSA analysis takes the revenue requirement for the utility and seeks to equitably allocate those costs to the various customer classes of service (i.e., residential, general service, etc). This analysis provides a determination of the level of revenue responsibility of each class of service and the adjustments required to meet the cost of service.

Costs are allocated to the various customer classes of service based upon the cost -causal relationships with the production and delivery of the services. A COSA begins by functionalizing a utility’s revenue requirement such as power supply, transmission, distribution, and customer. Next, the functionalized costs classify demand-, energy-, and customer-related component costs. Demand-related costs are those that the utility incurs to meet a customer’s maximum instantaneous usage requirement and are usually measured in kilowatts (kW). Energy -related costs are those that vary directly with longer periods of consumption, usually measured in kilowatt-hours (kWh). Customer-related costs are those that vary with the number and type of customers served.

These three component costs allocate to each class of service based upon the most equitable method for each specific cost. At that point, the revenue requirement becomes fully allocated to each class of service for a determination of the necessary revenue adjustments between classes of service. The final step is the calculation of demand, energy, and customer unit costs for each class of customer or rate schedule. These unit costs provide valuable input into the rate design process.

2.2 LEGAL CONSIDERATIONS
This section describes the legal framework considered in the development of the recommended rates to ensure that the calculated cost of service rates provide a fair and equitable allocation of costs to each customer class.

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2.2.1 California Constitution‐Article XIII C (Proposition 26) California voters approved Proposition 26 on November 2, 2010. Proposition 26 amended Article XIII C of the State Constitution to expand the definition of “tax” to include “any levy, charge, or exaction of any kind imposed by a local government” with liste d exceptions. By means of these exceptions, Article XIII C classifies several types of charges, in addition to property -related charges, that are not taxes, such as charges for specific services or benefits, regulatory charges and penalties.

Article XIII C’s definition of “tax” lists the following exceptions: (1) a charge imposed for a specific benefit conferred or privilege granted directly to the payer that is not provided to those not charged, and which does not exceed the reasonable costs to the local government of conferring the benefit or granting the privilege; (2) a charge imposed for a specific government service or product provided directly to the payer that is not provided to those not charged, and which does not exceed the reasonabl e costs to the local government of providing the service or product; (3) a charge imposed for the reasonable regulatory costs to a local government for issuing licenses and permits, performing investigations, inspections, and audits, enforcing agricultural marketing orders, and the administrative enforcement and adjudication thereof; (4) a charge imposed for entrance to or use of local government property, or the purchase, rental, or lease of local government property; (5) a fine, penalty, or other monetary charge imposed by the judicial branch of government or a local government, as a result of a violation of law; (6) a charge imposed as a condition of property development; and (7) assessments and property-related fees imposed in accordance with the provisions of Article XIII D.

Proposition 26 also provides that the local government bears the burden of proving by a preponderance of the evidence that a levy, charge, or other exaction is not a tax, that the amount is no more than necessary to cover the reasonable costs of the governmental activity, and that the manner in which those costs are allocated to a payer bear a fair or reasonable relationship to the payer’s burdens on, or benefits received from, the governmental activity. Like the proportionality requirements of Article XIII D, assessment of rates under these requirements, if applicable, would be supported by the cost of service approach.

2.3 CEU REVENUE REQUIREMENT
A revenue requirement analysis compares the overall revenues of the utility to its expenses and determines the required overall adjustment to rate levels. The revenue requirement is the starting point for overall costs in the COSA, with all items in the r evenue requirement allocating across the various customer classes. The rate base for the utility is also an important component when developing allocation factors for the revenue requirement.

The total FY 2026 expenses are $96 million. Other Income includes non-rate revenues, interest, and net income from the telecommunications business unit. The Change in Net Position illustrates the utility’s plan to use operating reserves to balance the rate adjustment in each year. The FY 2026 electric revenue requirement collected through retail rates is $88.5 million (total expenses less Misc. Revenues).

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TAB LE 2-1: PROJE CTE D REVEN UE RE QUIREME NT WITH REC OMMEN DE D ADJUSTMEN TS FY: 2026 FY: 2027 FY: 2028 FY: 2029
Retail Rate Revenues
Base Rate Revenue1 $53,723,752 $84,008,011 $85,696,740 $87,419,416 PCA Revenue $8,094,473
Incremental Base Rate Adjustment $21,469,767 $1,191,466 $1,215,417 $619,924 Total Rate Revenues $83,287,991 $85,199,477 $86,912,157 $88,039,340 Expenses
Power Supply $48,654,541 $40,367,118 $43,902,140 $47,104,747 Transmission & Distribution $7,507,057 $7,792,326 $8,088,434 $8,395,795 Customer Accounts and Services $401,479 $416,736 $432,572 $449,009 General & Administrative $13,465,065 $13,976,738 $14,507,854 $15,059,152 Capital Improvement Projects $5,370,000 $6,478,000 $4,822,000 $3,640,000 Other Contributions $17,357,859 $17,371,458 $17,371,458 $17,371,458 Interest and Debt Service $3,210,019 $3,331,999 $3,331,999 $3,331,999 Total Expenses $95,966,020 $89,734,374 $92,456,456 $95,352,160 Misc. Revenues $7,497,127 $7,497,127 $7,722,041 $7,953,702 Retail Revenue Requirement $88,468,893 $82,237,246 $84,734,415 $87,398,458

Change in Net Position -$5,180,902 $2,962,231 $2,177,741 $640,883

Annual Rate Increase Each October 1: 3% 2% 2% 1%

1. Base rate revenue based on retail rates from prior year.

2.4 RATE BASE
The accompanying plant rate base associated with the FY 2026 revenue requirement is $47.9 million. The rate base reflects gross plant of $118.8 million, offset by accumulated depreciation and customer contributions. Distribution makes up 59.3% of gross p lant followed by 6% for general plant and 35% for production.

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2.6 PROJECTED LOAD FORECAST
Tables 2-3 summarize the forecast loads and service account data for FY 2026.

TABLE 2-3: FY 202 6 FORECASTED LOADS
Retail Sales
MWh
Average
Load Factor
Monthly
Demand, kW
Service
Accounts
Residential 102,813 27.3% 562,673 16,182
Small General Service 43,677 44.7% 93,065 1,688 Medium General Service 31,802 54.0% 121,237 376 Industrial 49,636 44.4% 160,100 50
TOU LGS 95,277 61.0% 285,199 22
Municipal 2,636 59.2% 5,642 207
Lighting 1,856 50.0% 8,572 124
Total System 327,696 1,236,488 18,649

2.7 PROJECTED REVENUES
Retail rate revenues are calculated based on forecasted load data and current rates. It is assumed that the PCA will continue at its current level through September 2025.

TAB LE 2-4: PROJE CTE D REVEN UE S FY 202 6
Base PCA (1) Total
Residential $16,113,202 $3,108,858 $19,222,060
Small General Service $8,630,903 $895,096 $9,525,999
Medium General Service $6,367,266 $820,883 $7,188,149
Industrial $9,389,114 $1,100,845 $10,489,959
TOU LGS $12,393,905 $12,393,905 $24,787,810
Municipal $642,613 $62,675 $705,288
Lighting $237,391 $39,823 $277,214
Total System $53,774,394 $18,422,086 $72,196,480

1. Assumes PCA continues at its current level through September 2025.

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3 Cost of Service Analysis
The goal of the COSA is to analyze costs and equitably assign those costs to customers equal with the cost of serving those customers. The founding principle of cost allocation is the concept of cost -causation.

Cost-causation evaluates which customer or group of customers causes the utility to incu r certain costs by linking system facility investments and operating costs to serve certain facilities to the services used by different customers. This section of the report will discuss the general approach used to perform the CEU COSA and supply a summary of the results.

3.1 COSA O VERVIEW AND GENERAL PRINCIPLES
A COSA allocates the costs of providing utility service to the various customer classes served by the utility based upon the cost-causal relationship associated with specific expense items. This approach is taken to develop a fair and equitable assignment of costs to each customer class so that customers pay for the costs that they cause. Because most costs don’t directly incur to any one type of customer, the COSA becomes an exercise in spreading joint and common costs among the various classes using fac tors appropriate to each type of expense. The COSA is the second step in a traditional three-step process for developing service rates. The first step is the development of the test period revenue requirement for the utility, which is the starting input for the COSA. The COSA spreads the revenue requirement across the various customer classes, creating per unit costs by class. In the third step, unit costs provide initial rate designs for each customer class, with consideration of the proper rate levels.

The cost basis for a COSA study is typically embedded or marginal. Embedded costs reflect the actual costs incurred by the utility and closely track the costs kept in its accounting records. Marginal costs reflect the cost associated with adding a new customer and are based on costs of facilities and services if incurred at the present time. While marginal costs can be valuable for designing rates in certain instances, marginal costs are higher than embedded costs. Therefore, the use of a marginal COSA usually requires that all costs be scaled back to a level equal to the embedded cost revenue requirement established using actual or projected costs from an accounting perspective.

GDS used an embedded cost based on this COSA as its standard method. Therefore, the cost basis is CEU’s embedded cost revenue requirement and existing rate base investment for developing the COSA results.

There are three basic steps to follow in developing a COSA, namely:

◼ Functionalization
◼ Classification
◼ Allocation

Functionalization separates costs into major categories that reflect the utility’s plant investment and different services provided to customers. The primary functional categories are production, transmission, distribution, and general.

Classification determines the part of the cost that is related to specific cost -causal factors, such as those that are demand -related, energy -related, or customer -related. Production costs relate to supplying power to customers on the system. Production facilities operate to meet system peak demands and total energy requirements. Transmission costs relate to the bulk transfer of power to load centers on the system. These transmission facilities operate to meet system peak demand requirement. The distribution

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system extends service to all customers attached to the system and to meet the peak load capacity requirement of each customer.

FIGURE 3-1: FUNC TION ALIZ ATION , CLASSIFICATION AN D ALLOC ATION FLOW C HAR T

The study bases allocation of costs to specific customer classes on the customer’s contribution to the specific classifier selected. For instance, demand -related costs allocate to a customer group using that customer group’s contribution to the measuremen t of system demand, whether coincident peak, non - coincident peak, or some variation appropriate for the cost item.

GDS completed an analysis of customer requirements, loads, and usage characteristics to develop allocation factors reflecting each of the classifiers employed within the COSA. GDS based demand and energy allocation factors on actual demand data for 2022, with some adjustments to account for monthly billing results.

3.2 MAJOR ASSUMPTIONS OF THE COST -OF-SERVICE ANALYSIS The following provides some of the major assumptions and underlying data used in conducting this COSA for CEU.

Customer classes of service refer to the arrangement of customers into groups that reflect common usage characteristics or facility requirement. The classes of service used within this study were as follows:

The classes of service analyzed in the study are summarized in Table 1-2.

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TAB LE 3 -2 C OSA CUSTOMER C LASSE S
Size Average Number of
Accounts FY 2026
Residential Any 16,182
General Service < 20 kW 1,688
Medium General Service 20-200 kW 376
Large General Service (TOU 1 LGS) >200 kW 22
Industrial >200 kW 50
Municipal Any 207
Lighting N/A 124
Total

18,649

CEU is projecting increasing energy sales through the forecast period. There are a total of 18,649 metered services on average for FY 2026 and gross energy consumption of approximately 327,696 MWh.

Residential customers make up 87 percent of the total number of customers and 31 percent of energy sales. In contrast small general Service customers make up only 9 percent of customers and contribute 13 percent of total retail sales. The annual peak is forecast to occur in the summer at a level of 79 MW.

The following sections provide the specific treatment of items within the COSA, along with the results of the COSA.

3.3 FUNCTIONALIZATION OF COSTS
The first step in the COSA process is to functionalize the rate base and revenue requirement.

Functionalization is the separation of cost data into the functional activities performed in the operation of a utility system (i.e., power supply, transmission, distribution, and customer service). Functionalization uses CEU’s system of accounts for both the rate base and revenue requirement, which largely segregates costs in this manner. Revenue requirement items associated with certain types of plant were gen erally treated in the same manner as the corresponding plant account.

The bullet list below specifies functions used for CEU’s COSA. The functions generally follow standard cost of service approaches.

◼ Power Supply. The power supply function includes both rate base and expense items associated with generation owned by the utility and power purchase expenses.

◼ Transmission. The transmission function includes those costs for operating and maintaining the transmission lines, poles, towers, substations, etc., used to deliver power to the distribution network’s load centers. Transmission is generally those lines measured at 35,000 volts and above.

◼ Distribution. Distribution services include all services required to move the electricity from the point of interconnection between the transmission system and the distribution system to the end user of the power. These include substations, poles, primary and seconda ry poles and conductors, line transformers, services, and meters as well as customer costs and any direct assignment items. The distribution function includes c ustomer-related services, even for those customers served at the transmission voltage level. These services include meter reading, billing, collections, advertising, etc.

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Primary distribution is at voltages of 750 to 35,000 volts while secondary distribution has voltages of 750 volts or less.

The two areas where there generally are differences in functionalization among utilities are in the treatment of general plant and general and administrative (G&A) expenses. Typically, general plant is a separate category in the rate base. Functionalization spreads the general plant rate base across the three other functions. On the expense side, G&A costs spread in much the same way. Generally, each is a separate expense category that can be spread across the primary functions.

3.3.1 Functionalization of Plant Rate Base
CEU has $41.1 million in production plant rate base (accounts 330 to 335). All of these accounts are functionalized to power supply. Transmission is excluded since CEU does not own or maintain transmission assets. Distribution plant rate base is the biggest functional component of the CEU system and includes $70.5 million in rate base (accounts 360 to 373). These costs are all functionalized as distribution.

TAB LE 3-1: FUN CTION ALIZ ATION OF PLANT ACC OUNTS
Description Cost Account(s) Amount (millions) Functionalized to:

Production 310-346 $41.1 Production
Transmission 350-359 - Transmission
Distribution 360-373 $70.5 Distribution
General Plant

389-397.5 $7.2
38% Production
62% Distribution
Total Gross Plant $118.9

General plant for CEU is $7.2 million and includes computer and office equipment, transportation equipment and other items that are used by employees serving all three functional areas. Gross plant for CEU is $118.9 million. Accumulated depreciation is equal to $70.9 million resulting in a net plant amount of $47.9 million. Table 3-2 summarizes the functionalization of the rate base. Each of the accumulated depreciation accounts was treated in the same fashion as the corresponding gross plant accounts.

TAB LE 3-2: FUN CTION ALIZ ATION OF FY 2024 PLANT R ATE B ASE (NE T) Rate Base Category ($) Total Production Distribution
Intangible Plant $0 $0 $0
Production $41,077,275 $41,077,275 $0
Distribution $70,533,888 $0 $70,533,888
General Plant $7,247,068 $2,769,795 $4,477,274
Accumulated Depreciation ($70,928,898) ($30,398,578) ($40,530,320) CWIP1 $490,739 $0 $490,739
Total $48,420,072 $13,448,491 $34,971,581
Percent of Total 100% 27.8% 72.2%

1. Construction Work In Progress.

3.3.2 Functionalization of Revenue Requirement
CEU has a net revenue requirement from rates of $88.5 million for the 2026 fiscal year. In allocating the revenue requirements, expense items often follow the treatment of the corresponding rate base items.

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For example, total production/power supply costs are projected at $48.6 million for FY 2026 and are all functionalized to production.

Total distribution expenses are projected at $7.5 million and are annual expenses associated with the distribution rate base accounts. All distribution system operation and maintenance expenses are functionalizes to distribution.

CEU has $ 0.4 million in customer service expenses. These costs all functionalize to the Distribution Function.

General and Administrative ( G&A) costs for CEU are forecast at $13.5 million. Like general plant, these costs relate to all functions of the utility and often associate with the number of employees of the utility.

The study relies on O&M ratios to functionalize these costs to production and distribution (excluding power supply).

Depreciation expenses are $0. Generation depreciation follows generation etc. Depreciation for general plant and deferred charges follow the gross plant before general plant.

CEU is planning to for $5.4 million in capital projects. As is required by the City’s policy, these expenses must be rate funded. Capital projects are functionalized as Distribution except general plant investments.

General plant investments are functio nalized as Shared Services. Similar to the G&A costs, this means a portion of the costs are functionalized as Production and a portion are functionalized as Distribution.

CEU has planned for $3.2 million in interest and debt service expense for FY 2026 and does not plan to increase its debt funding.

The last expense category is “Other Contributions.” These include primarily the transfer to the General Fund. The City’s voters have approved that CEU transfer up to 20% of its annual revenue to the City’s General Fund. The General Fund transfer is a payment in lieu of taxes or franchise agreement. This transfer is estimated at $17 million for FY 2026 based on the retail revenue projection , and it is functionalized as Shared Services.

In addition to revenues from retail customers, CEU receives revenues from other activities, such as pole attachment fees and California Air Resources Board carbon auction revenue . Because the COSA is concerned with collecting revenues from rates by customer class, the other revenues of the utility are treated as an offset to the revenue requirement. Other revenues are therefore credited back to customer classes in a manner that fits the specific revenue item. Table 3-3 shows the estimated FY 2026 Misc.

Revenues and their Function.

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TAB LE 3 -3. M ISC. RE VEN UE FUN C TION ALIZ ATION
FY 2026 Function
Pole Attachment Revenue $12,623 Distribution
Interest & Dividend Income $348,628 Shared Services
Transmission Revenue $1,175,464 Shared Services
Damage to City Property $40,069 Shared Services
CA ARB Proceeds $3,150,993 Production
Service and Connect Fees $0 Distribution
Rents $666,347 Distribution
Other Income $162,468 Shared Services
Refunds, Rebates, Reimbursements $948,724 Shared Services Sales for Resale $0 Production
Misc Service Revenues $272,613 Shared Services
Development Fees $719,200 Shared Services
Total Misc. Revenues $7,497,127

Table 3-4 Shows the Functionalization results for the Revenue Requirement.

TAB LE 3-4: FUN CTION ALIZ ATION OF FY 202 6 RE VEN UE REQ UIREMEN T Revenue Requirement Category Total Production Distribution Production/Purchased Power $48,654,541 $48,654,541 $0 Distribution O&M $7,507,057 $0 $7,507,057
Customer Service/Accounts $401,479 $0 $401,479
Admin & General $13,465,065 $4,092,950 $9,372,115
Depreciation $5,370,000 $397,483 $4,972,517
Interest & Debt Service $3,210,019 $985,718 $2,224,300 Other Contributions $17,357,859 $310,024 $17,047,835
Other Revenues ($7,497,127) ($3,885,591) ($3,611,537)
Total $88,468,893 $50,555,126 $37,913,767

3.4 CLASSIFICATION OF COSTS
The second step in performing COSA is to classify the functionalized expenses to traditional cost-causation categories. These cost-causation categories can be directly related to specific consumption behavior or system configuration measurements such as coincident peak (CP) or non-coincident peak (NCP) demand, energy, or number of customers. Each classification category will have a specific allocator that, when applied, will distribute those costs among the proper customer classes during the allocation phase of the analysis.

The three primary classifiers are:

◼ Demand
◼ Energy
◼ Customer

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Functionalized power supply costs split between demand and energy. Transmission system costs classify as demand related. Distribution costs are split between demand -related and customer -related components or directly assigned to a specific customer class of service.

Within the three categories, there are multiple ways of defining each option as well as varying ways to split costs between two or more classifiers. For example, demand- and energy-related costs can separate by seasonal distinctions as well as to reflect peak/off peak consumption periods. Customer categories can distinguish between actual customer and weighted customer characteristics. Other classifiers sometimes used in the process include revenue-related and direct assignment. In addition, there are many instances where costs are not specifically classified as a category but in the same manner as an individual cost account or subtotal of specific cost accounts.

3.4.1 Classification of Generation and Transmission Rate Base Generation classification can follow several different methods, most of which rely on looking at the use of various types of plants and their purpose within the system. GDS maintained specific classification methods from other industry standard studies.

3.4.2 Classification of Distribution Rate Base
Generally, there are two methods for classifying distribution costs: 100% demand and minimum system.

The 100% demand methodology assumes that the distribution system is built to meet the non-coincident peak (NCP). The minimum system approach splits the distribution plant into customer -related and demand-related costs. The customer -related costs are based on the cost of a system designed to serve each customer a theoretical 1 kWh of energy per year. This results in a system cost made up of the smallest sized equipment. The share of the plant value that is remaining is classified as demand-related.

It is the cost of the system designed to meet customer needs.

The process of cost classification is the area within the COSA that can create considerable cost variability between customer classes due to differences in system configurations, demand measurements and system planning criteria. The complexity of the enti re COSA process compounds, in some cases, the classification category is clear, but the specific allocator is not. For example, a particular cost item may clearly be peak demand-related, but that demand can be measured as either a single coincident peak (1 CP) for the year, a combined winter and summer coincident peak (2 CP) approach to reflect seasonal considerations, the sum of 12 monthly coincident peaks (12 CP), or through some other approach.

Distribution services include all services required to transport energy supply from the point of transmission interconnection to the utility’s load centers and end user of the power. Classifying distribution costs requires a special analysis of the nature of the costs. Most distribution costs appropriately split between demand and customer components. The demand portion is the cost of facilities built to serve a load, such as distribution substations. The customer portion is the cost of facilities that varies with the number of customers, such as meters. Different accounts within the distribution function require separate treatment. For purposes of this COSA, GDS developed minimum system assumptions based on similar municipal systems in order to classify distribution rate base into demand and customer components.

3.4.3 Classification of Production/Power Supply Expenses Classifying power supply costs to demand and energy components depends on the use of the generation and the pricing for power supply purchases. When a utility has numerous generating facilities, the use of

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the various units to supply baseload versus peaking power should be considered. In the case of CEU, the power supply resources include long term power purchase contracts through CEU’s membership with SCPPA. CEU has a diverse portfolio consisting of hydropower purchases from the Hoover dam, wind, solar, geothermal, and natural gas plants. The classification and allocation methodology for each resource was developed based on a deta iled review of fixed and variable operating costs. The share of costs that a re variable result in an energy classification. The share of costs that are fixed (capacity-related) are functionalized as demand. Table 3-5 shows the demand and energy splits for CEU’s production costs.

TAB LE 3-5: POWER SUPPLY CLASSIFICATION
Classification Notes
Production 100% Demand Gas Turbine
Power Purchases 28% Demand
72% Energy
Magnolia, Palo Verde, Casa Diablo, Hoover, Wind,
Power Scheduling, Purchased Transmission
Total System 33% Demand
67% Energy Sum of all Resources

On a combined basis, the total production and purchased power expenses were classified 33% demand- related and 67% energy-related.

3.5 ALLOCATION OF COSTS
The third step in performing a COSA is the allocation of the utility’s total functionalized and classified revenue requirement to the customer classes of service. This is performed through the application of a proper allocation methodology.

For each of the primary classifiers discussed above, distinctions within each category better reflect cost - causation. The following are the specific allocation methods used in CEU’s COSA. The specific method of cost classification and allocation for various rate base and expense items is discussed in further detail below.

3.5.1 Demand Allocation Factors
For purposes of this study, three types of demand allocation factors were developed.

◼ Non-Coincident Peak Demand Allocation Factor (NCP). First, the study develops a non-coincident peak demand allocation factor for each customer class. Expenses classif y and allocate by the non - coincident peak demand allocation factor including those predicated on maximum demands such as distribution substations, and a portion of poles and lines, transformers, meters, and services. The NCP demand method allocates costs to each class of service based upon their highest non-coincident peak demand regardless of the time of occurrence. These NCP demand allocators are further separate into NCP at primary (NCPP) and secondary voltages (NCPS).

◼ Monthly Coincident Peaks (CP). For each class of service, a contribution to the system coincidence peak in each month derive s from the non -coincident peak and the use of a coincidence factor.

Coincident peaks allocat e the demand -related po rtion of power purchases as they differ in each month based on system usage.

◼ 12 Coincident Peaks (12 CP). Coincident peaks typically allocate a portion of production costs and all of transmission costs because of sizing for the system peak.

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3.5.2 Energy Allocation Factors
Energy costs vary directly with consumption. Accordingly, energy allocation factors base on electricity sales for each class. For purposes of monthly power supply costs, the energy in each month is the allocator.

3.5.3 Customer Allocation Factors
The study uses two basic types of customer costs—actual and weighted.

◼ Actual Customers (CUST). The allocation factor for actual customers derives from the actual number of customers served in each class of service, averaged across the 12 months of the 2024 FY test period.

◼ Customers Weighted for Meters and Services (CUSTM). The first weighted customer allocation factor considered the relative differences among the various customer classes of meter costs. The typical cost of a new meter for each rate class is the weighting factor for each class. CEU supplied updated costs for metering and services.

◼ Customers Weighted for Accounting/Metering (CUSTW). The second weighted customer allocation factor considered the cost of customer accounting and meter reading by each rate class. The weighting factors for CUSTW are the same as the ones developed in the previous study. and updated based on current metering costs.

3.5.4 Other Allocation Factors
Other costs allocate based on specific rate base items, O&M function totals, revenues, and special allocators.

3.5.5 Allocation of Rate Base
For the demand-related components of distribution, the NCPP is the allocation factor. Customer-related expenses are allocated based on customer count or a weighted count of customers such as for meters and services where customers with higher use are weighted more to account for the increased size of their meter and services.

General plant costs allocate to classes on the same basis as was used for each of the classified components.

Each of the accumulated depreciation accounts allocates in the same fashion as the corresponding gross plant accounts. Working capital items allocates on the same basis as the distribution rate base.

3.5.6 Allocation of Revenue Requirements
Because power supply purchases vary by month, power supply costs classify to demand and energy for each month and then allocate to customer classes based on the class contribution to system peak and energy loads for each month.

Distribution expense accounts correspond to a rate base account and follow allocation of the rate base item. For example, Maintenance of Station Equipment is allocated based on the Station Equipment

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allocation in the Rate Base. Station equipment is demand classified and allocated based on NCPP. As such, the annual expenses follow this same methodology.

For customer service expenses, meter reading, customer billing and customer assistance allocate on customers weighting for accounting/metering. Credit and collections expenses are allocated based on customers.

G&A costs functionalize using labor ratios and then classify and allocate on the same basis as the rate base for each of the three functions. This follows the same treatment described for general plant.

Depreciation expenses follow the allocation treatment used by the associated functional accounts.

Depreciation for general plant and deferred charges follow the gross plant before general plant.

Interest expense is allocated on the same basis as the total rate base (net plant).

Other Contributions include the General Fund Transfer and taxes. The General Fund transfer is allocated based on revenues. The PERS tax is allocated based on all other O&M expenses.

CEU receives revenues from retail sales to customers, as well as for other activities, such as pole attachment fees. Because the COSA studies collecting revenues from rates by customer class, the other revenues of the utility are an offset to the revenue requirement. Other revenues credit back to customer classes in a manner that fits the specific revenue item. Table 3-6 shows the detailed classification and allocation methodology for Misc. Revenues.

TAB LE 3 -6. M ISC. RE VEN UE C LASSIFIC ATION
FY 2026 Classification & Allocation
Pole Attachment Revenue $12,623 Distribution Rate Base
Interest & Dividend Income $348,628 Revenue
Transmission Revenue $1,175,464 Based on Distribution O&M Damage to City Property $40,069 Revenue
CA ARB Proceeds $3,150,993 Energy
Service and Connect Fees $0 Distribution Rate Base
Rents $666,347 Distribution Rate Base
Other Income $162,468 Based on Distribution O&M
Refunds, Rebates, Reimbursements $948,724 Based on Distribution O&M Sales for Resale $0 Energy
Misc Service Revenues $272,613 Based on Distribution O&M Development Fees $719,200 Based on Distribution O&M
Total Misc. Revenues $7,497,127

3.6 LOAD ANALYSIS
To allocate costs within the COSA, a combination of customer, demand and energy factors are used. The customer and energy allocations are straightforward as both the number of customers and energy per class are easy to track and forecast. Demand per cust omer class is more difficult as there are several

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different types of demand that are considered including the maximum demand for the individual meter, the maximum demand for the rate class and the actual demand for the rate class at the time of the overall system peak.

A key factor in a robust COSA is detailed load and consumption data on all customer classes. CEU supplied monthly aggregated load data from all customers by rate class for historical FY 2022- 2024. Having good aggregate data by rate class enabled GDS to use actual load and peak relationships from the historical period to develop FY 2026 cost allocation factors for all rate classes.

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4 COSA Results
Given the above assumptions regarding the COSA, the various costs classify and allocate to the customer classes of service. The results of the analysis include both revenues to costs and unit costs for each rate class. This section expands on the summary results earlier in the report based on specific findings of the updated study.

TAB LE 4-1: TOTAL PLAN T R ATE B ASE
FY24
Residential 19,050,906
Small General Service 5,524,861
Medium General Service 3,854,636
Industrial 5,205,250
TOU LGS 10,256,629
Municipal 241,438
Lighting 4,286,352
Total System $48,420,072

The FY 2026 net revenue requirement of $88.5 million classified into various components and allocated to customer classes. Retail revenues at current rates are compared to the Revenue Requirement in Table 4-2.

TAB LE 4-2: C OSA RE SULTS: FY 2026
Revenues at Current
Rates1
Allocated Revenue
Requirement
Revenue to Cost
Ratio(2)
Residential $19,222,060 $32,826,673 83%
Small General Service $9,525,999 $11,247,349 121%
Medium General Service $7,188,149 $8,023,971 127%
Industrial $10,489,959 $12,222,484 122%
TOU LGS $24,787,810 $22,657,111 92%
Municipal $705,288 $576,802 171%
Lighting $277,214 $914,502 44%
Total System $72,196,480 $88,468,893 100%

1. Includes PCA revenue through September 2025.

2. Adjusted to Recover 100% of the Revenue Requirement.

Overall, CEU needs a significant base rate increase. In addition, the rate levels among the rate classes need adjustments to rebalance the recovery of costs with the cost of service. COSA unit costs and rate recommendations are provided in the next section of this report.

4.1 SUMMARY OF ALLOCATION RESULTS
Given the above assumptions of the COSA, the various costs were classified and allocated to the customer classes of service. This section supplies the results of the COSA in summary form. The body of the report describes additional detail from the analysis.

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The results of the COSA indicate that, at current rate levels, Residential, TOU LGS, and Lighting classes are under collecting in relationship to the cost to serve each class respectively. The recommended rates adjust the relative rate levels so that the revenue to cost ratios are balanced.

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5 Rate Design
This section of the report will provide a comparison of CEU’s current rates to the unit costs developed in the cost-of-service study as well as rate design recommendations. The rate level adjustments (% change) are reported in reference the CEU’s current rate levels which includes the PCA at $0.085/kWh for all customers.

5.1 CURRENT RATE DESIGN
The electric rates have up to four components: 1) a fixed monthly service charge (facilities charge) 2) volumetric rates , (3) demand charges, (4) Power Factor Adjustment, and (5) Public Benefits Charge.

Customers must pay the facilities charge regardless of energy use or demand.

• Facilities monthly service charge: the rates are established based on the size of the meter at the property receiving electric service and are calculated to recover a portion of the City’s fixed costs, such as meter reading and customer service.

• Variable rates : the rates are calculated based on the cost of wholesale electricity and transmission. Any remaining fixed costs that are not recovered through demand or facilities charges are also recovered from variable charges. An example is that residential rates typically recover a portion of the cost of maintaining the electric distribution system through energy variable charges. The variable rates are billed per kWh.

• Demand Charge: For demand-metered customers, demand charges recover the cost of demand- related power supply expenses and the cost of maintaining the electric distribution system. These charges are billed each month based on maximum kW. For time-of-use classes, demand is also calculated for the relevant time -of-use period and may not be the same as maximum monthly demand.

• Power Factor Adjustment: The power factor adjustment recovers the cost of inefficient use of power on the customer side of the meter. The power factor is the ratio of real power to apparent power. The power factor adjustment is billed per kVa.

• Public Benefits Charge – In 1996 the State of California required all publicly owned electric utilities to establish a charge for programs that would benefit the public such as low -income assistance, energy efficiency, and renewable resources. The Public Benefits Charge (PBC) is equal to 2.85% of the utility’s annual revenue requirement.

Combining the rates and billing determinants for each customer results in monthly bills and annual revenue.

With the current rate design, CEU collects the majority of its revenue through energy charges; however, expenses are largely driven by demand and customers. Figure 5 -1 indicates that demand and customer charges should be increased to better reflect the cost of service.

FIGURE 5-1: RE VEN UE VS. E XPE NSE S B Y FUNC TION

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There are two steps in the rate change process, the first is deciding the overall rate change. Second is deciding how to spread that rate increase or decrease across customer classes. An overall rate adjustment of 3% is recommended for FY 2026. The following recommendations are incorporated into the recommended rates:
◼ Adjust rates annually by the recommended revenue adjustments for each rate class. ◼ Rebalance customer class rate levels to recover the rate class cost of service. These adjustments may result in rate adjustments that differ from the total adjustment. ◼ Increasing the fixed proportion of rate collection to align with COSA results ◼ Simplify the rate structure.
◼ Update time-of-use rate design to reflect current market price signals and cost of service.

The rate proposals in this section were developed based on COSA unit costs to improve interclass equity.

5.2 RECOMMENDE D RATES
Proposed and COSA rates are provided for each class below.

5.2.1 Residential
The current residential rate consists of a facilities charge and 4 -tier energy rate. The COSA showed that the facilities charge should be increased significantly; however, the recommended rate adjusts this charge gradually over time to minimize bill impacts to customers.

Overall, the energy rates are reduced to account for the increase in facilities charge. Second, the tiered rate design is simplified over time as well. The first two tiers are combined in FY 2026 and the highest two tiers are combined in FY 2028. Most usage (73.3%) is in the first two tiers, 23.6 % of usage is in Tier 3, and only 3.1% in Tier 4. Maintaining the tiers encourages efficient use of electricity.

The PBC (currently $0.0029/kWh) is updated based on 2.85% of the total revenue requirement.

3%
91%
6%
Retail Revenues
Customer-Related Energy-Related
Demand-Related
4%
34%
62%
Expenses
Customer-Related Energy-Related
Demand-Related

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TAB LE 5-1. RE COMMEN DE D R ATES: RE SIDEN TIAL
Cost of
Service Unit
Costs
Current
Rates FY 2026 FY 2027 FY 2028 FY 2029
Facilities Charge,
$/month
$45.47 $3.00 $12.00 $15.00 $17.00 $20.00
Energy, $/kWh $0.233
Tier 1: First 250
kWh
$0.16500 $0.20460 $0.21278 $0.21916 $0.21916
Tier 2: 251-500
kWh
$0.27805
Tier 3: 501-1,500
kWh
$0.31270 $0.28143 $0.29269 $0.30147 $0.30147
Tier 4 over 1,500
kWh
$0.37705 $0.37000 $0.37000

Public Benefits
Charge $/kWh
$0.0029 $0.00767 $0.00712 $0.00732 $0.00754
Rate Adjustment 6.9% 5.3% 3.2% 2.1%

5.2.2 Small General Service
The recommended rates for Small General Service increase the Facilities charge over time, update the PBC, and implement revenue neutral adjustments to the tiered energy rate. Because the current rate level (when the PCA is included) recovers the cost of service for this class, the first 2 years of the study result in no overall rate changes for this class.

TAB LE 5-2. SM ALL GEN ERAL SERVICE < 20 KW
Cost of
Service
Unit
Costs
Current Rates
including PCA FY 2026 FY 2027 FY 2028 FY 2029
Facilities
Charge,
$/month
$18.54 Single Phase:
$14.00
Three Phase:
$17.50
Single Phase:
$25.00
Three Phase:
$30.00
Single Phase:
$27.00
Three Phase:
$32.00
Single Phase:
$29.00
Three Phase:
$35.00
Single Phase:
$33.00
Three Phase:
$40.00
Energy,
$/kWh
$0.2523
First 2,500
kWh
$0.27263 $0.25982 $0.25956 $0.26216 $0.26347
2,501-10,000
kWh
$0.28450 $0.27113 $0.27086 $0.27357 $0.27494
>10,000 kWh $0.28925 $0.27566 $0.27538 $0.27813 $0.27952

Public
Benefits
Charge $/kWh
$0.0029 $0.00767 $0.00712 $0.00732 $0.00754
Rate
Adjustment

0.0% 0.0% 1.3% 1.2%

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5.2.3 Medium General Service
The recommended rates for Medium General Service increase the Facilities charge over time, update the PBC, and implement revenue neutral adjustments to the tiered energy rate. Because the current rate level (when the PCA is included) recovers the cost of service for this class, the first 2 years of the study result in no overall rate changes for this class.

TAB LE 5-3. MEDIUM G ENERAL SER VICE > 20 KW AN D < 200 KW Cost of
Service
Unit
Costs
Current Rates
including PCA FY 2026 FY 2027 FY 2028 FY 2029
Facilities
Charge,
$/month
$46.56 Single Phase:
$14.00
Three Phase:
$17.50
Single Phase:
$30.00
Three Phase:
$35.00
Single Phase:
$32.00
Three Phase:
$37.00
Single Phase:
$35.00
Three Phase:
$40.00
Single Phase:
$40.00
Three Phase:
$50.00
Energy, $/kWh $0.08861
First 7,500
kWh
$0.26550 $0.23178 $0.21301 $0.20236 $0.18233
>7,500 kWh $0.27025 $0.23593 $0.21682 $0.20598 $0.18559

Demand,
$/kW-mo
above 20 kW
$41.75 $3.75 $10.00 $15.00 $20.00 $25.00
Public Benefits
Charge $/kWh
$0.0029 $0.00767 $0.00712 $0.00732 $0.00754
Rate
Adjustment

0.0% 0.0% 3.2% 0.0%

5.2.4 Time-Of-Use Rate Classes
The primary goal of the rate design is to accurately reflect the cost of service depending on the time of day energy is used. Typically , higher-priced energy results from the combination of high electricity demands and constrained resource output , which occurs after the sun sets when lower-cost solar resources are no longer producing energy. The marginal cost of energy for CEU is considered to be the hourly market prices at the SP15 (South of Path 15) trading hub , adjusted for the Colton service area location. These prices are used to update the time periods for the Industrial and TOU LGS rate schedules.

Because of the large penetration of solar resources in the California markets, the highest priced periods typically occur in the evening. This is demonstrated in the average hourly market pricing data shown in Figure 5-2.4 These market prices are the marginal cost of electricity. In case of resource production surpluses or shortages, the City would sell or purchase energy at these prices. Figure 5-2 illustrates the

4 Average hourly prices for SP15, August 2021-July 2024.

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average hourly market pricing for the 3 -year period August 2021 -July 2024. 5 This period is the most relevant to the analysis since it is the most recent data available. This is because the shape of the pricing curves is more important than the pricing levels.

FIGURE 5 -2 AVE RAGE HOURLY WHOLE SALE E NE RGY PR ICE S

The current summer season is May 25 through September 25. In reviewing monthly power costs, and best practices in the State, it is recommended that October be added to the Summer season.

Based on the pricing data, it is recommended that the time-of-use periods be updated according to Table 5-5. The recommended rate design removes the three-period design in summer months. The result is an on-peak period that is consistent year-round from 4 pm to 9 pm every day. The simplification will make it easier for customers to remember when it’s more costly to use electricity and can help reduce bills and overall power costs to the utility.

5 While the natural gas shortage in winter 2023 inflated pricing in that period, removing that data from the analysis did not result in significant differences.
0 20
40 60
80 100
120
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Average Wholesale Prices, $/MWh
Hour Ending

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TAB LE 5 -5. C UR RENT AN D PR OPOSE D TIME -OF -USE PERIODS Current Recommended
Summer: May 25-September 25 Summer: May 25-October 25
On-Peak: Weekdays 12 pm to 6 pm Except Holidays On-Peak: 4 pm to 9 pm Every Day Mid-Peak: Weekdays 6 pm to 11 pm Except Holidays Off-Peak: All Other Hours Off-Peak: All Other Hours

Winter: September 26-May 24 Winter: October 26-May 24
Mid-Peak: Weekdays 8 am to 9 pm Except Holidays On-Peak: 4 pm to 9 pm Every Day Off-Peak: All Other Hours Off-Peak: All Other Hours

Table 5-6 and 5-7 show the recommended rates for Industrial and TOU LGS. Not only are the time periods updated, but also the demand charges are increased to reflect the cost of service results.

Because demand rates are increased, energy rates are decreased when necessary to meet the rate adjustment indicated at the bottom of each table.

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TAB LE 5-6. TOU LAR GE GENER AL SER VICE > 200 KW
Cost of Service Unit
Costs
Current Rates
including PCA FY 2026 FY 2027 FY 2028 FY 2029
Facilities Charge, $/month $49.85 $797.50 $797.50 $797.50 $797.50 $797.50 Energy, $/kWh $0.09138
Summer On-Peak $0.26480 $0.26339 $0.25022 $0.24021 $0.23060 Summer Mid-Peak $0.18443
Summer Off-Peak $0.17786 $0.12664 $0.12031 $0.11550 $0.11088 Winter Mid-Peak/Peak $0.18443 $0.19634 $0.18653 $0.17907 $0.17191 Winter Off-Peak $0.17622 $0.13749 $0.13061 $0.12539 $0.12037 Demand, $/kW-mo
Facilities, $/kW-mo $31.23 $3.37 $14.00 $16.00 $18.00 $20.00 Summer On-Peak $17.61 $11.48 $14.00 $16.00 $18.00 $18.00 Summer Mid-Peak/Peak $2.87
Winter Mid-Peak $17.61 $2.87 $6.00 $8.00 $10.00 $12.00
Power Factor Adjustment
$/kVar
$0.6525 $0.6525 $0.6525 $0.6525 $0.6525
Public Benefits Charge $/kWh $0.0029 $0.00767 $0.00712 $0.00732 $0.00754 Rate Adjustment 0.0% 1.5% 2.6% 1.6%

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TAB LE 5-6. IN DUSTR IAL > 200 KW
Cost of Service Unit
Costs
Current Rates
including PCA FY 2026 FY 2027 FY 2028 FY 2029
Facilities Charge, $/month $116.85 $659.18 $659.18 $659.18 $659.18 $659.18 Energy, $/kWh $0.09138
Summer On-Peak $0.25369 $0.29067 $0.27323 $0.25410 $0.23885 Summer Mid-Peak $0.24523
Summer Off-Peak $0.24033 $0.17472 $0.16424 $0.15274 $0.14358 Winter Mid-Peak/Peak $0.24522 $0.26784 $0.25177 $0.23415 $0.22010 Winter Off-Peak $0.23820 $0.18969 $0.17831 $0.16583 $0.15588 Demand, $/kW-mo
Facilities, $/kW-mo $33.01 $4.04 $14.00 $16.00 $18.00 $20.00 Summer On-Peak $20.47 $10.28 $14.00 $16.00 $18.00 $18.00 Summer Mid-Peak $2.58
Winter Mid-Peak/Peak $20.47 $2.37 $6.00 $8.00 $10.00 $12.00 Power Factor Adjustment
$/kVar $0.53923 $0.53923 $0.53923 $0.53923 $0.53923
Public Benefits Charge $/kWh $0.0029 $0.00767 $0.00712 $0.00732 $0.00754 Rate Adjustment 0.0% 0.0% 0.0% 0.0%

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5.2.5 Lighting
Finally, the lighting class rates are updated as shown in Table 5-7. The rates are increased by 15% per year. These rates apply to non-City customers who choose to have CEU maintain an unmetered light.

These can be area lighting, parking lighting, or other uses.

TAB LE 5-7. LIG HTIN G : DUSK TO DAWN
Current with
PCA FY2026 FY2027 FY2028 FY2029
70 Watts $0.21900 $0.24798 $0.26798 $0.28798 $0.30798
100 Watts $0.22798 $0.24798 $0.26798 $0.28798 $0.30798
150 Watts $0.19641 $0.21641 $0.23641 $0.25641 $0.27641
250 Watts $0.18255 $0.20255 $0.22255 $0.24255 $0.26255
400 Watts $0.14976 $0.16976 $0.18976 $0.20976 $0.22976

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Electric Cost of Service and Rate
Study – Draft Report
April 4, 2023
Colton
Electric
Utilities
P R E P A R E D B Y G D S A S S O C I A T E S , I N C .

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RESOLUTION NO. R-28-25

A RESOLUTION OF THE CITY COUNCIL OF THE CITY
OF COL TON REPEALING RESOLUTION R -39-13,

AMENDING EXISTING ELECTRIC RATES AND

CHARGES, CREATING A NEW ELECTRIC RATE

STRUCTURE, ADOPTING A POLICY ON CONDUCTING

ELECTRIC RATE STUDIES, AND UPDATING THE CITY

OF COLTON FINANCIAL POLICIES

WHEREAS, the City Council has the authority to prescribe, revise and collect charges for the services and facilities furnished by the electric energy enterprise within the Colton Electric Utility (“Utility”), and to otherwise amend, fix and/or establish the rates to be charged for the sale of electric energy, as well as all other deposits and charges in connection therewith (such charges are collectively referred to herein as “Rate” or “Rates”); and

WHEREAS, the City Council has previously adopted electric Rates for customers in the City pursuant to Resolution No. R-39-13, and the exhibits thereto; and

WHEREAS, the City Council desires to amend the Rates, as set forth and described in Exhibit “A” attached hereto and incorporated herein by this reference; and

WHEREAS, the revised Rates adopted by this Resolution have been available for public review in the Office of the City Clerk for two weeks prior to the public hearing on this Resolution; and

WHEREAS, a notice of public hearing on the proposed adoption of this Resolution was published in The Sun Newspaper, a newspaper published and circulated in the City of Colton, once each week for two (2) consecutive weeks prior to the public hearing on the following dates: April 25, 2025, and May 1, 2025; and

WHEREAS, the City Council also desires to adopt a Policy on Conducting Electric Rate Studies (the “Rate Study Policy ”), attached as Exhibit “ B” hereto, in order to establish a structured approach for conducting electric rate studies to ensure fair, transparent, and cost-effective electricity pricing for City of Colton rate payers while maintaining the financial stability of the Utility, and to support City Council priorities while aligning with State regulatory and compliance requirements; and

WHEREAS, the City Council further desires to adopt amended City of Colton Financial Policies (the “Financial Policies ”), attached as Exhibit “ C” hereto , increasing the Electric Enterprise’s cash working capital reser ve funds as further described in the Financial Policies in order to ensure, among other things, sufficient reserve funds for the Electric Enterprise.

NOW THEREFORE, THE CITY COUNCIL OF THE CITY OF COLTON
DOES HEREBY RESOLVE AS FOLLOWS:

Commented [RW1]: BBK: Charles, could you please fill in all highlighted portions of this resolution.

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SECTION 1. The foregoing recitals are true and correct and are incorporated herein by this reference.

SECTION 2. A public hearing was held on May 6, 2025 to consider revising the existing electric Rates. During the public hearing, all interested persons were given the opportunity to appear and present evidence and testimony concerning any matter relating to this Resolution and the proposed Rates.

SECTION 3. The City hereby determines that: (a) the proposed new Rates are imposed for a specific government service or product provided directly to the payor that is not provided to those not charged, and which does not exceed the reasonable costs to the local government of providing the service or product ; and (b ) the proposed new Rates will be in compliance with applicable law.

SECTION 4. The City hereby adopts the Rates as set forth in Exhibit “ A” hereto.

The increased Rates shall take effect on October 1, 2025.

SECTION 5. The City hereby further adopts, by way of this Resolution, the attached Rate Study Policy and Financial Policies, which shall become effective immediately upon adoption of this Resolution.

SECTION 6. This Resolution shall repeal any other action, resolution, or portions thereof, to the extent that such action, resolution, or portions thereof are in conflict with this Resolution.

SECTION 7. If any provision, section, paragraph, sentence, or word of this Resolution is rendered or declared invalid by any court of competent jurisdiction, or by reason of preemptive legislation, the remaining provisions, sections, paragraphs, sentences, and words of this Resolution shall remain in full force and effect.

SECTION 8. The Mayor shall sign this Resolution and the City Clerk shall attest thereto, and this Resolution shall take effect and be in force on the date of its adoption.

ADOPTED this 6th day of May, 2025.

___________________________________
Frank J. Navarro
Mayor

ATTEST:

___________________________________
Isaac T. Suchil
City Clerk

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EXHIBIT “A”

NEW AND AMENDED ELECTRIC ENERGY RATES AND CHARGES FOR THE COLTON ELECTRIC UTILITY (EFFECTIVE OCTOBER 1, 2025)

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[SEE ATTACHED ONE (1) PAGE TITLED:

“PROPOSED COLTON ELECTRIC UTILITY RATE SUMMARY
EFFECTIVE DATE: OCTOBER 1, 2025”

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EXHIBIT “B”

A POLICY ON CONDUCTING ELECTRIC RATE STUDIES

[Policy Attached on Following Page]

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EXHIBIT “C”

CITY OF COLTON FINANCIAL POLICIES

[Policy Attached on Following Page]

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23152.08000\43702222.1

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STATE OF CALIFORNIA )
COUNTY OF SAN BERNARDINO) ss.

CITY OF COLTON )

I, ISAAC T. SUCHIL, City Clerk of the City of Colton, do hereby certify that foregoing Resolution No. R-28-25 was duly and regularly adopted by the City Council of the City of Colton at a regular meeting thereof on the 6 th day of May, 2025 and that the same was passed and adopted by the following vote, to wit:

AYES:

NOES:

ABSENT:

ABSTAIN:

_________________________________
Isaac T. Suchil
City Clerk

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ITEM NO. 3

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: ISAAC SUCHIL, CITY CLERK
SUBJECT: APPROVAL OF MINUTES FOR THE CITY COUNCIL SPECIAL JOINT MEETING HELD ON APRIL 07, 2025, AND THE CITY
COUNCIL REGULAR MEETING HELD ON APRIL 15, 2025, ON FILE IN THE OFFICE OF THE CITY CLERK.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Approval of Minutes for the City Council Special Joint Meeting Held on April 7, 2025 and the City Council Regular Meeting Held on April 15, 2025.

BACKGROUND
Approval of Minutes for the City Council Special Joint Meeting Held on April 07,2025 and the City Council Regular Meeting Held on April 15, 2025.

ATTACHMENT

1. 04-07-2025 - Minutes Draft

2. 04-15-2025 - Draft Minute
3 Packet Pg. 72
1 CITY OF COLTON
City Hall, Council Chambers
650 N. La Cadena Drive
Colton, CA 92324
Website: www.coltonca.gov

Mayor Frank J. Navarro
Council Members & Elected:

David J. Toro – District 1
Kelly J. Chastain – District 2
Dr. Luis S. Gonzalez – District 3
John R. Echevarria – District 4

City Clerk Isaac T. Suchil
City Treasurer Henry M. Razo

City Manager William R. Smith
City Attorney Carlos Campos

SPECIAL JOINT MEETING MINUTES

OF THE CITY COUNCIL FOR THE CITY OF COLTON AND

THE UTILITIES COMMISSION FOR THE CITY OF COLTON
MONDAY, APRIL 7, 2025 – 5:30 P.M.

CITY HALL, COUNCIL CHAMBERS

OPEN SESSION
5:30 P.M.

Meeting held on the above given date at 5:30 p.m., in the Council Chamber of City Hall, with Mayor Navarro presiding.

CITY COUNCIL & UTILITIES COMMISSION ROLL CALL
Councilmembers present were MPT Toro, CM Chastain, CM González, CM Echevarria (joined the meeting at 5:36 p.m.) and Mayor Navarro.

Commissioners present were Larry Rivas, Eric Strutz, Nicolas Zupkofska, Kirk Larson; Victor Villareal was absent and excused.

STAFF PRESENT
Staff members present were City Manager William R. Smith, City Attorney Carlos Campos, Finance Director Stacey Dabbs and Electric Utility Director Charles Berry. Amber Gschwend from EES Consulting was also present.

MAYOR AND COUNCIL ITEMS
GIFT DISCLOSURES - None

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2 AB 1234 ORAL REPORTS - None
MAYOR AND COUNCIL DISCUSSION ITEMS - None

BUSINESS ITEM
(1) Electric Rate Workshop

Electric Rate PowerPoint was Presented by the Electric Utility Director, Charles Berry, and the Finance Director, Stacey Dabbs.

PUBLIC COMMENT
The following community and business members addressed the Council:

Andrea Pratt, VP. Government And Utility Relations, spoke on the electric rate proposal(s) and how it would hurt big electric rate power users.

All public comments can be reviewed on our Colton City Website (www.coltonca.gov).

COUNCIL AND UTILITIES COMMISSION DISCUSSIONS & QUESTIONS Discernment and discussion between Councilmembers and Commissioners present, with clarification provided by staff: Electric Utility Director Charles Berry, Finance Director Stacey Dabbs, and City Manager William R. Smith.

The following was recommended by the City Council to staff:
• Power Cost Adjustment Reduced to $.04, currently at $.08 • Reduces revenues by $4.3M through October 2025
• No additional rate action required beyond current recommendations • One-time revenue reduction can be absorbed
The above recommendation was supported by the majority of the City Council.

The City Council also asked that staff reports and any PowerPoint agenda materials be submitted in a timelier manner for their review, and that any future rate increases be submitted to the City Council for their review.

Comments from the Mayor and Council can be reviewed on our Colton City Website (www.coltonca.gov).

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3 CITY MANAGER COMMENTS:

William Smith expressed his commitment that staff would provide all agenda materials in a timely manner. Smith also said he would work on reviewing the current policy on rate increases recommended by staff.

ADJOURNMENT
Mayor Navarro adjourned the Special Council Meeting at 8:04 p.m.

___________________
Isaac T. Suchil
City Clerk

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City Hall, Council Chambers
650 N. La Cadena Drive
Colton, CA 92324
Website: www.coltonca.gov

Mayor Frank J. Navarro
Council Members:

David J. Toro – District 1
Kelly J. Chastain – District 2
Dr. Luis S. Gonzalez – District 3
John R. Echevarria – District 4

City Clerk Isaac T. Suchil
City Treasurer Henry M. Razo

City Manager William R. Smith
City Attorney Carlos Campos

REGULAR MEETING MINUTES

CITY COUNCIL,

COLTON UTILITY AUTHORITY, COLTON PUBLIC FINANCING AUTHORITY,

COLTON HOUSING AUTHORITY

REGULAR MEETING
TUESDAY, APRIL 15, 2025 – 5:00 P.M.

CITY HALL, COUNCIL CHAMBERS
CLOSED SESSION - 5:00 p.m.

Closed Session Meeting held on the above given date at 5:00 p.m., in the Council Chamber of City Hall, with Mayor Navarro presiding.

CITY COUNCIL ROLL CALL
Councilmembers present were MPT Toro, CM González, and Mayor Navarro; CM Chastain and CM Echevarria were absent.

PUBLIC COMMENT - Closed Session – None
City Attorney Campos announced the City Council would meet in Closed Session to Discuss Items A and B.
.

A. CONFERENCE WITH LEGAL COUNSEL - EXISTING LITIGATION
Pursuant to Government Code Section 54956.9(d)(1)
United States, et al. ex rel John Hendrix v. J -M Manufacturing Company Inc., and Formosa Plastics Corporation, U.S.A.

San Bernardino County Superior Court, Case No. ED CV06-00055-GW

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2 B. CONFERENCE WITH LABOR NEGOTIATORS
Pursuant to Government Code Section 54957.6
Agency Designated Representatives: Bill Smith, City Manager Employee Groups:

Teamsters - General Employees
Teamsters - Mid-Manager Employee Association
International Brotherhood of Electric Workers, Local 47 - Electric Division International Brotherhood of Electric Workers, Local 47-Water/Wastewater Division Colton Police Officers Association (CPOA)
Colton Police Management Association (CPMA)
Colton Police Dispatchers Association (CPDA)
Colton Police Civilian Employee Association (CPCA)
Colton Firefighters Association (CFA)
Confidential Employees Group

Mayor Navarro adjourned to Closed Session at 5:01 p.m. and Councilmember Chastain joined Closed session at 5:0 7. The meeting was reconvened at 6:00 p.m., with all members being present at 6:00 p.m.

City Attorney Reports/Reportable Action

City Attorney Campos announced that the City Council met in Closed Session and discussed Items A and B; direction was given but there was no reportable action.

OPEN SESSION

Regular Meeting held on the above-given date at 6:00 p.m. in the Council Chamber of City Hall, with Mayor Navarro presiding.

INVOCATION Pastor Eric Strutz - The Door Church
FLAG SALUTE Veteran and Mayor Pro Tempore, David Toro

CITY COUNCIL ROLL CALL

Council Members Present:

MPT Toro, CM Chastain, CM Gonzalez, CM Echevarria and Mayor Navarro.

The City Treasure, Henry M. Razo, and the City Clerk, Isaac T. Suchil, were also present.

City Staff Present:

City Manager William R. Smith
City Attorney Carlos Campos
CEREMONIAL MATTERS:
• Proclamation - Earth Day April 22, 2025 proclamation was read by Jessica Sutorus, who is the Environmental Conservation Supervisor.

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3 • Recognition – MPT Toro presented a certificate of recognition to Charles Berry, the Electric Utility Director, on behalf of the City of Colton’s Electric Utility department, for its exceptional performance and achievement in receiving the American Public Power Association’s Gold Reliable Public Power RP3 designation. • Recognition – CM Gonzalez presented recognition certificates to the members of the Youth Council for being outstanding students who have completed all requirements of the Youth Council; certificates were accepted by Kaley Diaz, Elizabeth Hernandez, Sienna Fernandez, Genesis Rodela Uriate and Sebastian Tabares.

MAYOR AND COUNCIL ITEMS

POSSIBLE CONFLICT OF INTEREST DISCLOSURES FOR THE COUNCIL.

GIFT DISCLOSURES
Mayor Navarro asked the members present if there were any agenda items that were a conflict of interest pursuant to CMC Section 2.04.030. None disclosed .

AB 1234 ORAL REPORTS
Mayor Navarro asked the members present if there were any brief reports on meetings attended at the expense of the city. (GC Section 53232.3(d). None disclosed

APPOINTMENTS
• Appointment(s) - GFT Committee Members were appointed by a consensus of the City Council and are as follows:

Richard De La Rosa and Veronica C. Gonzales

MAYOR AND COUNCIL DISCUSSION ITEMS

PUBLIC HEARINGS
(1) Fee Update - Community Services Department Fees & Rental Policies - TIME AND

PLACE FIXED TO CONSIDER A PUBLIC HEARING TO APPROVE AND

ADOPT A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF

COLTON UPDATING THE MASTER FEE SCHEDULE FOR SERVICES

PERFORMED BY THE COMMUNITY SERVICES DEPARTMENT,
RESOLUTION NO. R-20-25.

Mayor Navarro announced the Public Hearing Open.

City Clerk Suchil submitted the Notice of Public Hearing (on file in the City Clerk’s Office) and there were no protests or objections thereto.

A PowerPoint presentation was presented to the Council and to the public by the Recreation Services Manager, Heidi Strutz.

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4 There were no public comment cards submitted for this item.

Motion was made to close public hearing by Council Member Gonzalez with a second by Council Member Chastain; motion passed unanimously.

Council Discussion
Discernment and discussion between Mayor and Councilmembers present, with clarification provided by staff.

Comments made by Council and staff can be viewed on our city website at www.coltonca.gov.

Motion was made by MPT Toro, and a second by CM Echevarria, to approve and adopt Resolution No. R-20-25 and to update the master fee schedule for service performed by the community service department; motion passed unanimously.

BUSINESS ITEMS
(2) W/WW Capacity Fees - Approve the Water and Wastewater Capacity Fees Study and Waive Full Reading, Read by Title Only and Pass First Reading of Ordinances O-04-25 and O-05-25, Amending Title 13, Sections 13.04 and 13.16 of the Colton Municipal Code Establishing Water and Wastewater Capacity Charges, ORDINANCE NO. O-04-25 & O-05-25.

A PowerPoint presentation was presented to the Council and the public by the Public Works and Utilities Director, Chad Blais.

There were no public comment cards submitted.

Discernment and discussion between Mayor and Councilmembers present, with clarification provided by staff.

Comments made by Council and staff can be viewed on our city website at www.coltonca.gov.

A motion was made by CM Gonzalez, and a second by CM Echevarria, to approve the water and wastewater capacity fees study and waive full reading, read by title only and pass first reading of Ordinances No. O-04-25 and O-05-25, amending title 13, sections 13.04 and 13.16 of the Colton municipal code establishing water and wastewater capacity charges; motion passed unanimously.

(3) Summary Vacation of Right of Way and Declaration of “Exempt Surplus Land” – 910 Hert St. - Approve and Adopt a Resolution to Approve Summary Vacation of City Public Right of Way and Approve and Adopt a Resolution Approving the Declaration of City “Exempt Surplus Land” to Permit Disposition/Sale of Real Property – 910 Hert Street, RESOLUTION NO. R-24-25 & R-25-25.

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5 A PowerPoint presentation was presented to the Council and public by the Director of Development Services, Heidi Duron.

No public comment cards were submitted.

Discernment and discussion between Mayor and Councilmembers present, with clarification provided by staff.

Comments made by Council and staff can be viewed on our city website at www.coltonca.gov.

A motion was made by CM Gozalez, and a second by CM Echevarria, to approve and adopt a resolution to approve summary vacation of city public right of way and approve and adopt a resolution approving the declaration of city “exempt surplus land” to permit disposition/sale of real property – 910 Hert street; motion passed by majority vote with CM Chastain voting no.

PUBLIC COMMENT
The following community members addressed the Colton City Council and Mayor:

Pastor Pete Tasaka
Tish Ochoa, Colton Resident
Jose Guzman, Business Owner in Colton
Gayland Hernandez, Colton Resident
Daryl Terrell, Moreno Valley Resident
Nick Zupkofska, Colton Resident

CONSENT CALENDAR
Mayor Navarro presents the Consent Calendar Items 4 thru 19.

Motion and Second by CM González/ CM Chastain to approve consent calendar Items 4 through 19. Vote: Unanimous, Motion Passes

(4) Minutes - Approval of Minutes for the City Council Regular Meeting Held on March 18, 2025, and on April 1, 2025, on File in the Office of the City Clerk. [City Clerk: Isaac T. Suchil]

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6 (5) City Treasurer's Report - Receive and File City Treasurer's Report for October 2024.
[City Treasurer: Henry M. Razo]
(6) Warrants - Approve US Bank voucher dated 02/27/2025 totaling $8,590.35; replacement check number 218166 dated 03/12/2025 totaling $3,643.61; voucher numbers 218167 to 218260 dated 03/13/2025 and totaling $1,250,764.76 and voucher numbers 218261 to 218380 dated 03/20/2025 and totaling $3,304,016.80. [Staff Person: Stacey Dabbs]
(7) Agreement - Union Pacific Railroad (UPRR) - Approve Highway Overpass Agreement with Union Pacific Railroad (UPRR) for the Mt. Vernon Ave. Over UPRR Track Bridge Widening Project and Approve and Adopt a Resolution Amending the FY 24-25 Capital Improvement Budget for Mt. Vernon Ave. Over UPRR Track Bridge Widening Project, RESOLUTION NO. R-26-25. [Staff Person: Chad Blais]
(8) Change Order - Performance Construction & Painting - Approve Change Order #1 to Contract with Performance Construction & Painting for the Pool Deck Renovation Project at the Gonzales Center.
[Staff Person: Chad Blais]
(9) Change Order - Yoda Painting - Approve Change Order #1 to Contract with Yoda Painting for the Gonzales Center Painting Project.
[Staff Person: Chad Blais]
(10) Contract Amendment - SWAG - Approve Contract Amendment with Social Work Action Group (SWAG).
[Staff Person: Anthony Vega]
(11) Contract Award - CAT Tracking - Approve and Adopt a Resolution to Authorize the Award of Construction Contract for the South La Cadena Drive Bike Lane Project to Cat Tracking, Inc., RESOLUTION NO. R-22-25.
[Staff Person: Chad Blais]
(12) Contract Award - Triad Consulting & System Design Group - Approve Professional Services Agreement to Triad Consulting & System Design Group for Not to Exceed Amount of $270,090 for Engineering and Design Services for the City-Wide Integrated Security Solutions Project.
[Staff Person: Chad Blais]
(13) Emergency Condition - Agua Mansa Power Plant - Confirm Ongoing Emergency Condition at Agua Mansa Power Plant.
[Staff Person: Charles Berry]
(14) Grant Award - Equitable Community Revitalization (ECRG) Agreement - Approve and Adopt a Resolution to Approve the Third Amendment to Grant Award for the Equitable Community Revitalization (ECRG) Agreement, RESOLUTION NO. R- 15-25.
[Staff Person: Charles Berry]

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7 (15) Justice Assistance Grant (Jag) FY 2024 - Accept FY2024 Justice Assistance Grant (Jag) Award and Approve and Adopt a Resolution Approving the Budget Amendment to Reflect Purchase of Glock Handguns, Rifle Cases, Plate Carriers and Related Equipment, RESOLUTION NO. R-16-25.
[Staff Person: Anthony Vega]
(16) Grant Award - Homeless Housing Assistance & Prevention Program (HHAP) - Approve and Adopt a Resolution to Amend the FY 2024-2025 Budget and Accept Homeless Housing, Assistance and Prevention Program (HHAP-4) Grant Funds, RESOLUTION NO. R-02-25.
[Staff Person: Deb Farrar]
(17) Labor Plan Compensation Adjustments - Approve and Adopt a Resolution Approving Labor Plan Compensation Adjustments - Colton Police Civilian Employees Association (CPCEA), Teamsters Local 1932 - General Employees Unit (General Unit), Teamsters Local 1932 – Mid-Manager Employee Unit (MMA) and IBEW - Water/Wastewater, RESOLUTION NO. R-21-25.
[Staff Person: Tom Cody]
(18) Right of Way - Iowa Avenue - Approve Acceptance of Right-of-Way Easement for Public Street Purposes Along Iowa Avenue.
[Staff Person: Chad Blais]
(19) Signage - Panhandling - Approve Installation of "Say No to Panhandling" Signs. [Staff Person: Anthony Vega]

MAYOR AND COUNCIL ORAL REPORTS AND COMMENTS
Comments from Mayor and Council on various issues and activities throughout the City can be viewed on our city website at www.coltonca.gov
CITY MANAGER'S REPORTS – None

ADJOURNMENT
At 8:02 p.m. Mayor Navarro adjourned the Regular Council Meeting with a moment of silence in honor of Aurora Loli Leyva and Pedro Villarreal.

__________________________
Isaac T. Suchil
City Clerk

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ITEM NO. 4

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: STACEY DABBS, FINANCE DIRECTOR
SUBJECT: APPROVE VOUCHER NUMBERS 218381 TO 218459 DATED 03/26/2025 AND TOTALING $98,743.72; VOUCHER NUMBERS
218460 TO 218562 DATED 03/27/2025 AND TOTALING
$1,236,729.41, REPLACEMENT CHECKS 218563 TO 218564 DATED 04/01/2025 TOTALING $6,804.35; VOUCHER NUMBERS 218565 TO 218728 DATED 04/03/2025 AND TOTALING $1,492,953.27 AND
VOUCHER NUMBERS 218729 TO 218823 DATED 04/10/2025 AND
TOTALING $3,871,138.61.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Approve voucher numbers 218381 to 218459 dated 03/26/2025 and totaling $98,743.72; voucher numbers 218460 to 218562 dated 03/27/2025 and totaling $1,236,729.41, replacement checks 218563 to 218564 dated 04/01/2025 totaling $6,804.35; voucher numbers 218565 to 218728 dated 04/03/2025 and totaling $1,492,953.27 and voucher numbers 218729 to 218823 dated 04/10/2025 and totaling $3,871,138.61.

BACKGROUND

The California Government Code requires that the legislative body ratify all vouchers issued in the course of conducting City business.

ISSUES/ANALYSIS

All vouchers and related backup documentation have been reviewed by the Finance Director and City Manager.

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Staff Report to the Mayor and City Council
Warrants - Accounts Payable
May 6, 2025

Page 2 ends

FISCAL IMPACTS

None.

ALTERNATIVES

1. Provide alternative direction to staff.

ATTACHMENT

1. Fund Number and Title Legend

2. Voucher lists

3. Voucher lists.continued
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City of Colton
Fund Number and Title Legend
Fund Title Fund Title
100 GENERAL FUND 701 LLMD #2
150 TREASURERS ACCOUNT GROUP 702 LLMD #1
206 COMMUN ITY CHILD CARE 703 CFO 87-1 DEBT SERV ICE
209 DSF FLY CONSERVATION 704 CFO 87-1 CONSTRUCT ION
210 SPECIAL GAS TAX 707 CFO 88-1 DEBT SERV ICE
211 LIBRARY GRANT FUND 708 CFO 88-1 CONSTRUCTION
212 STATE TRAFFIC RELIEF FUND 709 DSF FLY CONSERVATION
213 S.Y.E.T .P. GRANT 722 STORM WATER
214 POLLUT ION REDUCT ION FUND 733 CFO 89-1 CONSTRUCT ION 215 COMMUNITY DEV ACT FUND 734 CFO 89-2 CONSTRUCT ION
216 CDBG HOUS ING REHAB FUND 744 CFO 89-1 DEBT SERV ICE 217 DRUG/GANG INTERVENTION 745 CFO 89-2 DEBT SERV ICE
218 MEASURE I FUND 750 AQUA MANSA CFO
219 STATE AID- CAPITAL PROJECTS 754 SB COUNTY HOSPITAL
220 Vi Tep 762 TRUST AND AGENCY
225 MISC GRANTS 766 DEFERRED COMPENSAT ION
240 HOST CITY FEES - CIP 781 CFO 90-1 DEBT SERVICE
247 Quimby In Lieu Fees 782 CFO 90-1 CONSTRUCT ION
248 PARK DEVELOPMENT FUND 850 Redeve lopment Obligation Retirement Fund 249 TRAFF IC IMPACT FUND 851 Successor Agency Administration 250 NEW FAC ILITIES DEVELOPMENT FEE 855 Hous ing Auth - RM PARK DEVELOPMENT 251 CIVIC CENTER DEVELOPMENT FEE 856 Housing Auth - RANCHO MED BOND PROCEEDS 252 FIRE FAC ILITY DEVELOPMENT FEE 857 LMI Asset Fund
253 POLICE FACILITY DEVELOPMENT FEE 864 Housing Auth - LOW/MOD BOND PROCEEDS 261 ASSET FORFEITURE 865 Housing Auth - RANCHO MED CHFA 326 AD 94-1 DEBT SERVICE 866 ECONOM IC DEVELOPMENT
332 1971 SEWER BONDS, A & C 867 Consolidation Proj_08 -09 350 PFA Debt Fund 870 Housing Auth - RM PARK OPERAT IONS 357 POB-Non Enterprise 871 Successor Agcy-RANCHO/M ILL PROJECT AREA 358 PENS ION OBLIGATION DEBT SERV ICE 872 Succe ssor Agcy-RANCHO/MILL DEBT SERV ICE 359 CORP YARD DEBT SERV ICE 873 Successor Agcy-RDA II PROJECT FUND 363 1978-2 ASSESSMENT DIST . 874 Housing Auth - LOW/MOD DEBT SERV ICE 364 WATER IMPRVMNT DIST A 875 Housing Auth - LOW/MOD BOND PROCEEDS 379 AD 1979-1 DEBT SERV ICE 876 Successor Agcy-SANTA ANA RIV BND PROCEED 427 AD 94-1 CONSTRUCT ION 877 Successor Agcy-SANTA ANA RIVER CIP 450 Capita l Improvement Project s 878 RDA FIXED ASSETS GROUP 451 Colton Crossing Fund 879 Successor Agcy-WEST VALLEY CIP 453 STREET IMPROVEMENTS PRGM 881 Successor Agcy-MT VERNON BOND PROCEEDS 457 CAP ITAL IMPROVEMENT 882 Successo r Agcy-MT VERNON CIP 469 EQU IPMENT REPLACEMENT 885 Successor Agcy -MT VERNON DEBT SERV ICE 520 ELECTR IC UTILITY 886 RDA ADM INISTRAT ION
521 WATER UTILITY 887 COOLEY RANCH - now 894
522 WAS TEWATER UTILITY 888 MT VERNON - now 882
523 SOLID WASTE 889 WEST VALLEY - now 879
524 CEMETERY 890 Successor Agcy-RDA - LONG TERM DEBT GRP 525 RECYCLING 891 Successo r Agcy-RDA I DEBT SERV ICE FUND 526 PUBLIC BENEFIT FUND 892 Successor Agcy-RDA I - CAP ITAL PROJECTS 527 WASTEWATER UTILITY - GRAND TERRACE 893 Successor Agcy -RDA II DEBT SERV ICE FUND 551 WATER DEVELOPMENT 894 Successor Agcy -COOLEY RANCH PRO JECT 552 SEWER DEVELOPMENT 895 Successor Agcy-COOLEY RANCH DEBT SERV 560 CEMETARY ENDOWMENT CARE 896 SANTA ANA RIVER - now 877 605 Facility & Equipment Maintenance Fund 897 Successor Agcy-SANTA ANA RIVER DEBT SVC 606 INFORMATION SERV ICES FUND 898 Housing Auth - LOW/MOD CAPITAL PROJECTS 607 INSURANCE FUND 899 Successor Agcy-WEST VALLEY PRJ - DBT SV 608 AUTOMOT IVE SHOP 941 GENERAL LONG -TERM DEBT
610 AUTOMOT IVE SHOPS 958 GENERAL FIXED ASSETS
990 GASB 34

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ITEM NO. 5

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHARLES BERRY, ELECTRIC UTILITY DIRECTOR
SUBJECT: ENTER INTO THE FIRST AMENDMENT TO PHASE II

RENEWABLE DEVELOPMENT AGREEMENT WITH SOUTHERN

CALIFORNIA PUBLIC POWER AUTHORITY (SCPPA) FOR
RENEWABLE ENERGY DEVELOPMENT PROJECTS.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Authorize the City Manager or designee to execute the First Amendment to Phase II Renewable Development Agreement with Southern California Public Power Authority (SCPPA) for Renewable Energy Development Projects in the amount of $250,000.

BACKGROUND

The Southern California Public Power Authority (SCPPA) is a Joint Powers Authority, formed in 1980 under the Joint Exercise Powers Act of the California Legislature. The City of Colton (Colton) is one of eleven municipal utilities and one irrigation district that make up the SCPPA members. SCPPA manages power supply needs for its various members to help maximize economies of scale and reduce risk among other responsibilities.

On January 19, 2012, the SCPPA Board of Directors approved and adopted Resolution 2012 -008 to authorize SCPPA to execute a Phase II Renewable Development Agreement between SCPPA and each of its members to pursue renewable development projects.

On February 19, 2013, Colton City Council approved and entered into a Phase II Development Agreement with SCPPA to facilitate and pursue renewable projects on Colton’s behalf, with a not-to-exceed amount of $100,000 unless amended by both SCPPA and the City.

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This amendment will add additional funding in the amount of $250,000, for a total aggregate amount of $350,000, which will be expelled on an as -needed basis to facilitate negotiations of new projects.

ISSUES/ANALYSIS

Colton Electric Utility (CEU) has utilized SCPPA to perform joint member procurements for renewable projects to include, but not limited to Request for Proposals, proposal review, development agreement negotiations, project development, and project management services.

California Renewable Portfolio Standard (RPS) requires utilities to achieve a 60% renewable energy target by 2030, establishing a resource mix comprised of sustainable renewable energy resources. The passage of Senate Bill (SB) 100 in 2022 affirmed state policy that 100% of retail sales of electricity be sourced from carbon -free resources by 2045. Colton actively pursues eligible renewable energy resources to help fulfill the State mandated RPS target and continue its path towards a more sustainable power supply mix on behalf of its customers. This First Amendment to the Phase II Renewable Development Agreement will support CEU’s ongoing efforts to meet state RPS compliance.

FISCAL IMPACTS

Sufficient funds are available in the Fiscal Year 2024 -25 Budget, in Electric Utility Power Resource Development Professional Services Account Number 520-8000-8022-2350-0923-000.

ALTERNATIVES

Provide alternative direction to staff.

ATTACHMENT

1. Executed Phase II Development Agreement with Southern California Public Power Authority

2. Amendment No. 1 to the Phase II Development Agreement with Southern California Public Power Authority
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AMENDMENT NO. 1

TO THE PHASE II RENEWABLE DEVELOPMENT AGREEMENT

BETWEEN

SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY
AND

CITY OF COLTON

This Amendment No. 1 to the Phase II Renewable Development Agreement between the Southern California Public Power Authority (“SCPPA”) and the City of Colton (“City”) (the “Agreement”), is made and entered into this ____ day of ________________, 2025.

WHEREAS, on January 19, 2012, the SCPPA Board of Directors approved and adopted Resolution 2012-008 to authorize SCPPA to execute a Phase II Renewable Development Agreement between SCPPA and each of its Members, in order to, among other things, facilitate SCPPA’s pursuit of renewable development projects on behalf of its members and to bind City to pay for City’s share of costs associated with SCPPA’s pursuit of such renewable projects; and

WHEREAS, the Agreement was executed by City on February 19, 2013; and

WHEREAS, Section 6.1 of the Agreement between SCPPA and City provides that costs under the Agreement shall not exceed one hundred thousand dollars ($100,000) unless amended by SCPPA and the City; and

WHEREAS, City and SCPPA desire to amend the Agreement to increase the not-to- exceed amount provided in Section 6.1 of the Agreement by two hundred fifty thousand dollars ($250,000) for a new not-to-exceed amount of three hundred fifty thousand dollars ($350,000).

NOW, THEREFORE, in consideration of the premises herein, and for good and valuable consideration, the Parties agree as follows:

1. The fifth sentence of Section 6.1 of the Agreement is hereby amended to read as follows:

“Costs under this Agreement shall not exceed three hundred fifty thousand dollars ($350,000) without a further amendment of this agreement between SCPPA and the Participant which is signatory to this Agreement.”

2. Except as provided herein, all other terms and conditions of the Agreement shall remain in full force and effect.

3. The Parties may execute this Amendment by manual signature or by electronic signature, each of which shall have the same force and effect . A signed copy of this Amendment transmitted by facsimile, email or other means of electronic transmission shall be deemed to have the same legal effect as delivery of an original executed copy of this Agreement for all purposes, to the extent provided under applicable law, including California’s Uniform Electronic Transactions Act.

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IN WITNESS WHEREOF, each signatory hereto represents that he or she has been properly authorized to execute and deliver this amendment on behalf of the party for which he or she signs.

SOUTHERN CALIFORNIA PUBLIC POWER AUTHORITY

By:

DANIEL E GARCIA
Executive Director

Approved as to Legal Form:

ARMANDO ARBALLO
Assistant General Counsel

and;

CITY OF COLTON

By:

WILLIAM R. SMITH
City Manager

Attest:

ISAAC T. SUCHIL
City Clerk

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ITEM NO. 6

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: ANTHONY VEGA, POLICE CHIEF
SUBJECT: APPROVE OF CHANGE ORDER NO. 1 FOR THE POLICE

DEPARTMENT PARKING LOT EXPANSION PROJECT WITH
ROADWAY ENGINEERING & CONSTRUCTION CORP.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

1. Approve Change Order No. 1 for the Police Department Parking Lot Expansion Project with Roadway Engineering & Construction Corp. for $42,946.08; and

2. Authorize the City Manager to execute Change Order No. 1.

BACKGROUND

The Police Department, situated within the City Hall property, functions as the central hub for all its operations. On any given day, the department can have up to 50 employees on duty simultaneously. This staffing level, however, presents a significant challenge in terms of parking, as the available, secured, parking lot only accommodates 35 personal vehicles.

Consequently, this shortage of parking spaces creates logistical and safety issues for staff.

ISSUES/ANALYSIS

On February 5, 2025, the notice to proceed for the Police Department Parking Lot Expansion Project was issued to Roadway Engineering & Construction Corp. During construction it was discovered that the canopy in place that was being moved to a new location within the parking lot has a concrete foundation. Additional concrete foundation needs to be poured into the new area of the canopy. In addition, PD Staff decided to move the current generator to a new location within the parking lot to allow better space for movement in a future construction project. 6 Packet Pg. 303
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May 6, 2025

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Additional funding through this change order is needed to pour a new concrete pad for the relocation of the generator, as well trenching for new conduit. This work needs to be done now so that when the generator is moved in the future, the parking lot does not need to be torn apart and only movement and hook-up of the generator will be needed.

FISCAL IMPACTS

Sufficient appropriations for the change order are available in the FY2024 -25 adopted budget in the following accounts.

Funding Source Account No. Change Order
Funding
Building Maintenance Fund 605-6150-6211-4950-0000-000 $14,718.00 General Fund 100-6070-6071-3890-0000-000 $28,228.08
Total $42,946.08

ALTERNATIVES

1. Provide alternative direction to staff.

ATTACHMENT

1. PD Parking Lot Expansion - Change Order No. 1

2. COR #001 - Add Traffic Rated Pull Box

3. COR #002 - Pathway and Pad for Generator

4. COR #003.1 Provide Concrete Pad Install Canopy per RFI 006 6 Packet Pg. 304
DATE:

FROM: Jim McGivern
TO:

INSTRUCTIONS TO THE CONTRACTOR AT THE REQUEST OF THE PROJECT MANAGER:

Price Increase for add'l concrete pad for generator relocation and canopy. Add'l pull box, Credit for asphalt not needed I. INCREASED QUANTITY
Item No. Description of Work Quantit y Unit Unit Cost Total Cost 1 1.00 EA 9,800.00 $ = 9,800.00 $
2 1.00 EA 1,286.00 $ 1,286.00 $
3 1.00 EA 12,400.90$ 12,400.90 $
4 1.00 EA 15,827.18$ 15,827.18 $
5 236.00 LF 12.00 $ 2,832.00 $
6 4.00 TONS 200.00$ 800.00 $
TOTAL = 42,946.08$
II. DECREASED QUANTITY
Item No. Description of Work Quantity Unit Unit Cost Total Cost SUB-TOTAL = -$
TOTAL AMOUNT OF CHANGE ORDER #1 = 42,946.08$
III. CONTRACT AMOUNT RECONCILLATION
ORIGINAL AMOUNT OF CONTRACT = 323,531.00$
CHANGE ORDER NO.1 = 42,946.08$
TOTAL COST OF CONTRACT AS PER CHANGE ORDER NO. 1 = 366,477.08$

CITY OF COLTON
April 2, 2025
CONTRACT CHANGE ORDER NO. 1
6" PCC Pad for Canopy Relocation
PD Parking Lot Expansion Project

PUBLIC WORKS DEPARTMENT- ENGINEERING SECTION
Roadway Engineering
3121 Indian Ave.

Perris, CA 92571
Traffic rated pullbox and lid
Pad for Generator relocation - Roadway Engineering
Conduit and Trenching for Generator Pad Relocation
Construct PCC V-Gutter - 3' w/ drain openings
Construct Asphalt - Additional area
DATEChad Blais, Public Works/Utilitity Services Director The amount of the contract will be increased by the sum of$42,946.08 (13.27% of the contract amount) and contract time shall be extended by0 calendar days. The undersigned Contractor approves the foregoing Change Order # 1as to the changes, if any, in the contract price specified for each item including any and all supervision costs and othermiscellaneous costs relating to the change in work, and as to the extension of time allowed, if any, for completion of the entire work on account of said Change Order # 1. The Contractor agrees to furnish alllabor and materials and perform all other necessary work, inclusive of the directly or indirectly related to the approved time extension, required to complete the Change Order items. This document will become a supplement of the contract and all provisions will apply hereto. It is understood that the Change Order shall be effective when approved by the Owner.

Eric Alvarez, Roadway Engineering & Construction Corp. DATE Execution of this Change Order by the Contractor constitutes a binding accord and satisfaction that fully satisfies, waives, and releases the Ownerfrom all claims, demands, costs, and liabilities, in Contract, law or equity, arising out of or related to the subject of the change order, whether known or unknown, including but not limited to direct andindirect costs and/or damages for delay, disruption, acceleration, loss of productivity, and stacking of trades, as well as any and all consequential damages.

William R. Smith, City Manager DATE
1 of 1

6.a
Packet Pg. 305
Attachment: PD Parking Lot Expansion - Change Order No. 1 (4907 : Change Order - Roadway Engineering & Construction Corp.) ROADWAY ENGINEERING & CONSTRUCTION CORP.

General Engineering Contractor License #1073145

3121 Indian Avenue • Perris, California 92571 • (951) 940-0045 • FAX (951) 940-0046

March 21, 2025

City of Colton
160 S 10th St,
Colton CA 92324

Attention: Jim McGivern

Reference: Colton Police Department New Parking Lot Expansion Project

Regarding: COR #001 – Provide and Install Traffic Rated Pull Box for Existing Entry Gate Operator

Mr. McGivern,

Per your request, the total cost to provide and install a new traffic rated pull box to house the existing entry gate is $1,286.00. Adding this pull box will reduce the amount of time in which the gate will not be operatable. Attached you will find an itemized cost breakdown from Ryan Electric for this work.

If this price is acceptable, please issue a contract change order for this amount. Call me (951) 940-0045, if you have any questions.

Sincerely,

ROADWAY ENGINEERING

Rafael Gomez

6.b
Packet Pg. 306
Attachment: COR #001 - Add Traffic Rated Pull Box (4907 : Change Order - Roadway Engineering & Construction Corp.) Description of Change:

Extra Credit
a. Labor (quantity and unit cost attached) 525.55 0.00
b. Material (quantity and unit cost attached) 588.49 0.00 c. Equipment (quantity and unit cost attached) 0.00 0.00 d. Supervision 0.00 0.00
d. Subtotal 1,114.04 0.00

e. Subcontractor (quantity and unit cost attached) 0.00 0.00

f. Subcontractor's Overhead and Profit
not to exceed 10% 0.00 0.00
g. Subtotal 1,114.04 0.00
h. Ryan Electric, inc. Overhead and Profit
including extended home office overhead,
not to exceed 10% (no more than 5% if
work performed by Subcontractors) 111.40 0.00
i. Subtotal 1,225.44 0.00
j. Bond Premium, not to exceed 1% 0.00 0.00
k. Total 1,225.44 0.00
l. Total Credit
1 of 2
Ryan Electric, Inc.
1340 W. Princeton Street
P.909.465.0434
F.909.465.0438
[email protected], CA 91762
COST PROPOSAL CO # 1
Add underground pull box as to not interfere with gate operation

Colton PD Parking Lot Expansion

6.b
Packet Pg. 307
Attachment: COR #001 - Add Traffic Rated Pull Box (4907 : Change Order - Roadway Engineering & Construction Corp.) Date:

Description of Change:

DESCRIPTION QTY UNIT LABOR MAT EQUIP SUB TOTAL

LAB MAT EQP SUB
11x17 UG Pull Box H2O Rated 1 E 231.12 231.12 231.12
11x17 UG Steel Cover H2) Rated 1 E 357.37 357.37 357.37 Labor 5 H 105.11 525.55 525.55

TOTAL 525.55 588.49 0.00 0.00 1,114.04
Add 400amp 3P disconnect and fuse to 300amp

UNIT COST
Job: Colton PD 3/21/2025
Written by: Matt Ryan
MATERIAL AND LABOR BREAKDOWN CO #1
Colton PD Parking Lot Expansion
Per RFI #7 Response, Delet 300amp 3P breaker in main switchboard "MSA" & bus tap.

6.b
Packet Pg. 308
Attachment: COR #001 - Add Traffic Rated Pull Box (4907 : Change Order - Roadway Engineering & ROADWAY ENGINEERING & CONSTRUCTION CORP.

General Engineering Contractor License #1073145

3121 Indian Avenue • Perris, California 92571 • (951) 940-0045 • FAX (951) 940-0046

March 21, 2025

City of Colton
160 S 10th St,
Colton CA 92324

Attention: Jim McGivern

Reference: Colton Police Department New Parking Lot Expansion Project

Regarding: COR #002 – Provide Pathway and PCC Pad for Generator

Mr. McGivern,

Per your request, the total cost to provide an underground pathway and PCC pad for the existing generator to be relocated by others in the future is $28,228.08. Attached you will find an itemized cost breakdown from Roadway Eng, and Ryan Electric for this work.

Roadway Eng. Cost: $12,400.90
Ryan Elect Cost: $15,827.18
TOTAL $28,228.08

If this price is acceptable, please issue a contract change order for this amount. Call me (951) 940-0045, if you have any questions.

Sincerely,

ROADWAY ENGINEERING

Rafael Gomez

6.c
Packet Pg. 309
Attachment: COR #002 - Pathway and Pad for Generator (4907 : Change Order - Roadway Engineering & Construction Corp.) Details Report For : COLTON POLICE DEPARTMENT PARKING LOT EXPANSION ERIC ALVAREZ 03/28/2025
Item
U/MQuantity Unit Cost Margin% Unit Price Total PricePh. CO 01 PCC PAD FOR GEN AND AC PATCH

1.00 LS $12,400.90 $12,400.9015.00$10,783.39 $10,783.39 CHANGE ORDER Total Cost
Description
Activity Crew Activity QtyPCC PAD 1.00 LS
Days:Rate:

Day:

Hour:

Labor
Equipment
Total Cost:

Unit Cost:0.10

0.70 1.50

1.50 LS
LS
$6,568.05
Actual: 1.50
$6,568.05

PCC PAD
Labor Quantity DaysHours Unit Cost
GENERAL FOREMANGENFOR 1.00 8.00 HR 1.50 $1,581.00 131.75 LABORER GROUP 1LAB 1 1.00 8.00 HR 1.50 $1,100.76 91.73
CEMENT MASONMAS 2.00 8.00 HR 0.50 $765.52 95.69
OPERATOR GROUP 6OPER 6 1.00 8.00 HR 1.50 $1,499.88 124.99 Total$0.00 The total contains overtime cost of: $4,947.160.00 DaysHoursQuantityEquipment Unit Cost
$503.521.50HR8.00TRCREW CREW TRUCK 1.00 41.96
$442.001.00HR8.00MINI MINI EX (BARE) 1.00 55.25
$945.52Total
QuantityMaterial Unit Cost
$429.87PCCCON6SK 143.293.00
$115.50PCC FEESCONFEE 385.000.30
$130.00REBARREBAR 130.001.00
$675.37Total
Act
Note:

Page 1 of 3 ends

6.c
Packet Pg. 310
Attachment: COR #002 - Pathway and Pad for Generator (4907 : Change Order - Roadway Engineering & Construction Corp.) Details Report For : COLTON POLICE DEPARTMENT PARKING LOT EXPANSION ERIC ALVAREZ 03/28/2025
Item
U/MQuantity Unit Cost Margin% Unit Price Total PricePh. CO 01 PCC PAD FOR GEN AND AC PATCH

1.00 LS $12,400.90 $12,400.9015.00$10,783.39 $10,783.39 CHANGE ORDER Total Cost
Description
Activity Crew Activity QtyAC PATCH AND

REMOVE DEMO

1.00 LS
Days:Rate:

Day:

Hour:

Labor
Equipment
Total Cost:

Unit Cost:0.10

1.00 1.00

1.00 LS
LS
$4,215.34
Actual: 1.00
$4,215.34

AC PATCH AND REMOVE DEMO
Labor Quantity DaysHours Unit Cost
GENERAL FOREMANGENFOR 1.00 5.00 HR 1.00 $658.75 131.75
LABORER GROUP 1LAB 1 2.00 5.00 HR 1.00 $917.30 91.73
OPERATOR GROUP 6OPER 6 1.00 5.00 HR 1.00 $624.95 124.99 Total$0.00 The total contains overtime cost of: $2,201.000.00 DaysHoursQuantityEquipment Unit Cost
$209.801.00HR5.00TRCREW CREW TRUCK 1.00 41.96
$279.101.00HR5.00SKIP SKIPLOADER (BARE) 1.00 55.82
$252.701.00HR5.00RLGBV ROLLER (BARE) 1.00 50.54
$741.60Total
QuantityMaterial Unit Cost
$325.24ASPHALT CONCRETEAC 81.314.00
$325.24Total
QuantityTrucks Unit Cost
$810.0010 WHEELERTRK10W 135.006.00
$810.00Total
QuantityOther Unit Cost
$137.50DUMP FEE - ACDMP 275.000.50
$137.50Total
Act
Note:

Page 2 of 3 ends

6.c
Packet Pg. 311
Attachment: COR #002 - Pathway and Pad for Generator (4907 : Change Order - Roadway Engineering & Construction Corp.) Description of Change:

Extra Credit
a. Labor (quantity and unit cost attached) 6,937.26 0.00 b. Material (quantity and unit cost attached) 1,365.93 0.00 c. Equipment (quantity and unit cost attached) 5,400.00 0.00 d. Supervision 0.00 0.00
d. Subtotal 13,703.19 0.00

e. Subcontractor (quantity and unit cost attached) 0.00 0.00

f. Subcontractor's Overhead and Profit
not to exceed 10% 0.00 0.00
g. Subtotal 13,703.19 0.00
h. Ryan Electric, inc. Overhead and Profit
including extended home office overhead,
not to exceed 10% (no more than 5% if
work performed by Subcontractors) 1,370.32 0.00
i. Subtotal 15,073.51 0.00
j. Bond Premium, not to exceed 1% 0.00 0.00
k. Total 15,073.51 0.00
l. Total Credit
1 of 2
Ontario, CA 91762
COST PROPOSAL CO # 2
Addition of trench and two (2) 2" and one (1) 3" conduit to feed the generator at future location per request of Jim McGivern
Colton PD Parking Lot Expansion
Ryan Electric, Inc.
1340 W. Princeton Street
P.909.465.0434
F.909.465.0438
[email protected]

6.c
Packet Pg. 312
Attachment: COR #002 - Pathway and Pad for Generator (4907 : Change Order - Roadway Engineering & Construction Corp.) Date:

Description of Change:

DESCRIPTION QTY UNIT LABOR MAT EQUIP SUB TOTAL

LAB MAT EQP SUB
Saw Cut Asphalt 180' 1 1,100.00 1,100.00 1,100.00
Remove Asphalt 90'x18" 1 600.00 600.00 600.00
Trench 90' 1 2,100.00 3,100.00 3,100.00
3" PVC 100' C 236.71 236.71 236.71
3" PVC 90 1 E 16.73 16.73 16.73
3" PVC Cap 1 E 11.29 11.29 11.29
PVC Glue 1 E 34.39 34.39 34.39
3" FA 1 E 6.64 6.64 6.64
3"x12" GRC Nipple 1 E 45.32 45.32 45.32
3" Ground bushing 1 E 24.86 24.86 24.86
Underground Marker 1 1 135.71 135.71 135.71
Burial Tape 1 R 146.73 146.73 146.73
Duct Tape 1 R 7.32 7.32 7.32
3" PVC 45 3 E 26.53 79.59 79.59
2" PVC 200' C 123.44 246.88 246.88
2" PVC 90 2 E 5.32 10.64 10.64
2" PVC Cap 2 E 7.35 14.70 14.70
2" PVC FA 2 E 7.06 14.12 14.12
2"x12" GRC Nipple 2 E 29.38 58.76 58.76
2" Ground Bushing 2 E 11.61 23.22 23.22
2" PVC 45 6 E 5.64 33.84 33.84
Clean Up Asphalt 1 Lot 200.00 0.00 200.00 200.00
Ground Rod 1 E 87.78 87.78 87.78
#1 THHN Wire 20' M 2,246.11 44.92 44.92
Ground Clamp 1 E 85.78 85.78 85.78
Truck 16 H 25.00 400.00 400.00
Labor 66 H 105.11 6,937.26 6,937.26

TOTAL 6,937.26 1,365.93 5,400.00 0.00 13,703.19
McGivern

UNIT COST
Job: Colton PD 3/26/2025
Written by: Larry Schual
MATERIAL AND LABOR BREAKDOWN CO #2
Colton PD Parking Lot Expansion
Addition of trench and two (2) 2" and one (1) 3" conduit to feed the generator at future location per request of Jim

6.c
Packet Pg. 313
Attachment: COR #002 - Pathway and Pad for Generator (4907 : Change Order - Roadway Engineering & ROADWAY ENGINEERING & CONSTRUCTION CORP.

General Engineering Contractor License #1073145

3121 Indian Avenue • Perris, California 92571 • (951) 940-0045 • FAX (951) 940-0046

April 15, 2025

City of Colton
160 S 10th St,
Colton CA 92324

Attention: Jim McGivern

Reference: Colton Police Department New Parking Lot Expansion Project

Regarding: COR #003.1 – Provide Concrete Pad to Install Canopy per RFI 006

Mr. McGivern,

Per the response to RFI 006, the total cost to construct a new concrete pad to relocate the existing canopy is $9,800.00. Please note that this cost includes a credit for the 10 tons of asphalt that will be replaced by the concrete pad.

Cost for PCC Pad = $11,800.00
Credit for 10 tons of AC = -$2,000.00
TOTAL = $9,800.00

Attached you will find an itemized cost breakdown from Roadway Eng. for the cost of the PCC pad.

If this price is acceptable, please issue a contract change order for this amount. Call me (951) 940-0045, if you have any questions.

Sincerely,

ROADWAY ENGINEERING

Rafael Gomez

6.d
Packet Pg. 314
Attachment: COR #003.1 Provide Concrete Pad Install Canopy per RFI 006 (4907 : Change Order - Roadway Engineering & Construction Corp.) Details Report For : COLTON POLICE DEPARTMENT PARKING LOT EXPANSION ERIC ALVAREZ 04/15/2025
Item
U/MQuantity Unit Cost Margin% Unit Price Total PricePh. CO 03 PCC PAD A

T CANOPY

1.00 LS $11,800.00 $11,800.0015.0$10,256.30 $10,256.30
CHANGE ORDER Total Cost
Description
Activity Crew Activity QtyGRADE, FORM, REBAR
PAD

1.00 LS
Days:Rate:

Day:

Hour:

Labor
Equipment
Total Cost:

Unit Cost:0.10

1.00 1.00

1.00 LS
LS
$4,233.00
Actual: 1.00
$4,233.00

GRADE, FORM, REBAR PAD
Labor Quantity DaysHours Unit Cost
GENERAL FOREMANGENFOR 1.00 8.00 HR 1.00 $1,054.00
131.75
OPERATOR GROUP 6OPER 6 1.00 8.00 HR 1.00 $999.92 124.99 LABORER GROUP 1LAB 1 1.00 8.00 HR 1.00 $733.84 91.73
Total$0.00 The total contains overtime cost of: $2,787.760.00 DaysHoursQuantityEquipment Unit Cost
$167.841.00HR4.00TRCREW CREW TRUCK 1.00 41.96
$446.561.00HR8.00SKIP SKIPLOADER (BARE) 1.00 55.82
$201.801.00HR4.00RLGBV ROLLER (BARE) 1.00 50.45
$229.041.00HR4.00TRW200 WATER TRUCK (BARE) 1.00 57.26
$1,045.24Total
QuantityMaterial Unit Cost
$400.00REBARREBAR 400.001.00
$400.00Total
Act
Note:

Page 1 of 2 ends

6.d
Packet Pg. 315
Attachment: COR #003.1 Provide Concrete Pad Install Canopy per RFI 006 (4907 : Change Order - Roadway Engineering & Construction Corp.) Details Report For : COLTON POLICE DEPARTMENT PARKING LOT EXPANSION ERIC ALVAREZ 04/15/2025
Item
U/MQuantity Unit Cost Margin% Unit Price Total PricePh. CO 03 PCC PAD A

T CANOPY

1.00 LS $11,800.00 $11,800.0015.0$10,256.30 $10,256.30
CHANGE ORDER Total Cost
Description
Activity Crew Activity QtyPOUR PCC PAD 1.00 LS
Days:Rate:

Day:

Hour:

Labor
Equipment
Total Cost:

Unit Cost:0.10

1.00 1.00

1.00 LS
LS
$6,023.30
Actual: 1.00
$6,023.30

POUR PCC PAD
Labor Quantity DaysHours Unit Cost
GENERAL FOREMANGENFOR 1.00 4.00 HR 1.00 $527.00
131.75
CEMENT MASONMAS 2.00 8.00 HR 1.00 $1,531.04 95.69
LABORER GROUP 1LAB 1 2.00 8.00 HR 1.00 $1,467.68 91.73
Total$0.00 The total contains overtime cost of: $3,525.720.00 DaysHoursQuantityEquipment Unit Cost
$335.681.00HR8.00TRCREW CREW TRUCK 1.00 41.96
$224.001.00HR4.00TRFORM FORM TRUCK 1.00 56.00
$559.68Total
QuantityMaterial Unit Cost
$1,432.90CONCRETE 6 SACKCON6SK 143.2910.00
$385.00PCC FEESCONFEE 385.001.00
$120.00FORMSFORMS 120.001.00
$1,937.90Total

Page 2 of 2 ends

6.d
Packet Pg. 316
Attachment: COR #003.1 Provide Concrete Pad Install Canopy per RFI 006 (4907 : Change Order - Roadway Engineering & Construction Corp.)

ITEM NO. 7

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHARLES BERRY, ELECTRIC UTILITY DIRECTOR
SUBJECT: APPROVE CONTRACT AMENDMENT NO. 4 WITH NINYO &

MOORE TO COMPLETE ENVIRONMENTAL WORK AT
CORPORATE YARD.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Authorize the City Manager or designee to execute Amendment No. 4 to the Professional Services Agreement (PSA) with Ninyo & Moore, to complete Phase II Environmental with additional amendments to the scope of work from the Department of Toxic Substance Control, per terms of the PSA, including exhibits attached thereto.

BACKGROUND

The City of Colton has been working on a preconstruction design for a future Zero Net Energy (ZNE) Public Works and Utilities building in the current location of 160 S. 10 th Street. During the initial Geotechnical request for proposals (RFP), a land covenant/deed restriction was discovered on Assessor Parcel Number 163-041-38 in the City’s corporate yard.

The City applied for funding to mitigate the land use covenant. On July 1, 2022, the Department of Toxic Substance Control (DTSC) contacted the City of Colton as the selected inaugural grantee for the Equitable Community Revitalization Grant (ECRG) in the amount of $280,000.

City Council accepted the grant award September 6, 2022, with approval of Resolution No. R - 98-22.

Council has awarded the contract to Ninyo & Moore as the lowest responsive and responsible bidder in accordance with Colton Municipal Code Sections 3.08.020 and 3.080.050(G) on 7 Packet Pg. 317
Staff Report to the Mayor and City Council
Contract Amendment - Ninyo & Moore
May 6, 2025

Page 2 ends

February 21, 2023. With these funds, staff has completed Phase I Environmental and is currently working on Phase II with Ninyo & Moore.

ISSUES/ANALYSIS

After the first scoping meeting with DTSC, it was determined that additional site investigation work needed to be completed outside of the original scope of work that was awarded to Ninyo & Moore. DTSC wanted a Supplemental Site Investigation (SSI) Scoping Meeting, SSI workplan preparation, and implementation of the SSI for the City of Colton Maintenance Service Yard located at 160 South 10th Street in Colton, California (site). The additional cost for Amendment No. 1 to the contract was $49,590, approved by City Council on July 18, 2023. On March 28, 2023 Ninyo and Moore submitted Amendment No. 2 for additional work per the direction of DTSC. The additional cost to Amendment No. 2 was approved by Council on November 17, 2023 for $8,652.

After a conference call between the City of Colton, DTSC and Ninyo & Moore on December 12, 2023, it was determined that in addition to submitting a proposal for an Addendum to the SSI workplan, additional costs for the implementation of the addendum SSI Workplan and preparation of the removal action plan (RAW) to address site cleanup should be included in the amendment to the City of Colton Maintenance Service Yard location.

Amendment No. 3 was approved by the council on February 6, 2024, based on DTSC comments on December 12, 2023. From this approval, the Supplemental Site Investigation Addendum Report was submitted to DTSC for comments and approval. DTSC res ponded with a conditionally approved supplemental site investigation report requesting a deeper soil vapor impact investigation associated with a clarifier and wash rack where elevated levels of PCE and chloroform were discovered.

Staff recommend approving Amendment No. 4 with Ninyo and Moore , to complete the site investigation request as they are familiar with the project and have been instrumental in receiving the additional grant funds from DTSC.

The amount requested in Amendment No. 4 is $177,000, which brings the total value of the agreement for services to $ 247,644 which is funded fully from DTSC grant awards . This will complete the site investigation fieldwork and the cleanup action plan.

FISCAL IMPACTS

Sufficient appropriations for the proposed $ 177,000 contract amendment are available in the FY 2024-25 adopted budget in Electric Utility Fund Capital Improvement Expenditure Account Number 520-8000-8001-3890-0107-000 upon approval of Resolution No. R-15-25.

ALTERNATIVES
7 Packet Pg. 318
Staff Report to the Mayor and City Council
Contract Amendment - Ninyo & Moore
May 6, 2025

Page 3 ends

1. Provide alternative direction to staff
7 Packet Pg. 319

ITEM NO. 8

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: DEB FARRAR, COMMUNITY SERVICES DIRECTOR
SUBJECT: AWARD CONTRACT TO INNOVATIVE PLAYGROUND DESIGN

FOR INSTALLATION OF COOLEY RANCH STATE PRESCHOOL
PLAYGROUND.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

1. Award Construction Contract to Innovative Playground Design to install Playground Option 1 at Cooley Ranch State Preschool, not -to-exceed $ 199,838.70, by the established deadline of June 30, 2025

2. Authorize the City Manager to execute all contracts necessary to proceed.

BACKGROUND

The Cooley Ranch State Preschool is a City -operated early childhood education program located on a shared -use site with Cooley Ranch Elementary School, in partnership with Colton Joint Unified School District. This program provides access to high -quality, state -funded preschool services to families in the Colton community.

The preschool site does not currently have a designated, age -appropriate playground within the fenced area of the preschool . Outdoor learning and physical activity are essential components of early childhood development, and the absence of suitable play equipment limits the ability of the program to meet California Department of Education guidelines for high -quality preschool environments.

ISSUES/ANALYSIS

8 Packet Pg. 320
Staff Report to the Mayor and City Council
Contract Award - Innovative Playground Design
May 6, 2025

Page 2 ends

To address the longstanding need for a designated outdoor play area, the Community Services Department, Early Care & Education Division, identified the installation of a new playground at Cooley Ranch State Preschool as a priority capital project. Funding has been secured through a combination of State contract funds and American Rescue Plan Act (ARPA) allocations received over the past three fiscal years. The new playground is specifically designed for children ages 2 – 5 and will include developmentally appropriate play equipment, limited shading, and compliant safety surfacing to support physical activity and social development in a secure, age -appropriate environment.

In March 2025, the City initiated a formal procurement process through BidNet, the City’s approved online bidding platform. A detailed Request for Proposals (RFP) was posted publicly, outlining the project scope, technical specifications, compliance requirements, timeline, and evaluation criteria. To ensure all prospective bidders had a complete understanding of the project site and expectations, a mandatory job walk was held on April 8, 2025, at the preschool location.

Seven vendors attended the walk -through. Only vendors who participated in the job walk and submitted complete proposals by the stated deadline were considered during the evaluation phase.

Proposals were received from two qualified companies: Innovative Playgrounds and Great Western Recreation by the deadline of April 21, 2025 . Each submitted two design options at varying price points , with the understanding that installation must be completed no later than June 30, 2025, to remain compliant with State funding requirement.

City staff from both the Community Services and Public Works Departments conducted a thorough review of all submitted proposals. Each proposal met the minimum requirements, including ADA accessibility, CPSC and ASTM safety compliance, and demonstrated strong manufacturer reliability supported by solid reputations within the industry.

Following detailed evaluation, staff recommends awarding the playground installation contract to Innovative Playground Design for Design Option #1. This option was selected based on its superior balance of quality, inclusive design features, overall play value, and the vendor’s ability to deliver the project within the required timeframe. Design Option #1 offers a well-rounded play experience with multiple stations that promote physical, social, and cognitive development for preschool-aged children, while fitting efficiently within the existing site footprint. The total contract amount for this project is $199,838.70, which includes all equipment, materials, and installation services. The matrix below explores the price points and total score for each out of a total of 400:

Option 1 Option 2 Total Score
Great Western Recreation $ 281,225.64 $ 164,213.11 353 Innovative Playground Design $ 199,838.70 $ 185,755.58 367.5

The installation of a new playground at Cooley Ranch State Preschool will significantly enhance the learning environment, improve program quality, and ensure compliance with early childhood 8 Packet Pg. 321
Staff Report to the Mayor and City Council
Contract Award - Innovative Playground Design
May 6, 2025

Page 3 ends

education facility standards. With procurement complete and funding secured, the project is ready for implementation.

FISCAL IMPACTS

This project is funded through a combination of restricted State contract earnings and previously allocated American Rescue Plan Act (ARPA) funds. Specifically:
• State Contract Funds: A portion of the project cost will be covered by reimbursement - eligible earnings from the City’s ongoing participation in the California State Preschool Program (CSPP) contract. These funds are designated for facility improvements that support health, safety, and developmental outcomes for enrolled children. • ARPA Funding: The remaining balance will be funded through sub-recipient ARPA allocations designated for early childhood education and facility enhancements. These funds were previously accepted by the City Council and reserved for capital improvements benefiting underserved and high-need populations.

Sufficient appropriations for the contract are available in the FY2024-25 adopted budget in the following accounts:

Early Care & Education Fund – CSPP 206-7200-7202-3890-0000-000 $ 43,780.00 Early Care & Education Fund – ARPA 206-7200-7208-3890-0000-000 $156,058.70

ALTERNATIVES

1. Provide alternative direction to staff.

ATTACHMENT

1. RFP - Cooley Ranch State PreSchool Playground 3-17-25 final

2. Innovative Playgrounds Option 1

3. Timeline
8 Packet Pg. 322

8.a
Packet Pg. 323
Attachment: RFP - Cooley Ranch State PreSchool Playground 3-17-25 final (4917 : Contract Award - Innovative Playground Design)

8.a
Packet Pg. 324
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ITEM NO. 9

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHARLES BERRY, ELECTRIC UTILITY DIRECTOR
SUBJECT: CONFIRM ONGOING EMERGENCY CONDITION AT AGUA
MANSA POWER PLANT.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Confirm ongoing emergency conditions at Agua Mansa Power Plant and authorize the City Manager or designee to execute all necessary agreements to complete repairs to the power plant and simultaneously execute all necessary agreements with all vendors as required as provisioned in Colton Municipal Code § 3.08.130 (A).

BACKGROUND

On Friday, February 14, 2025, Ag ua Mansa Power Plant (AMPP) experienced a fault condition on the medium -voltage bus work interconnecting the generator switchgear to the step -up transformer. Upon investigation, the bus work is determined to be non -serviceable due to the extensive damage caused by multiple faults. Due to this non -serviceable status, the bus work, which is a proprietary product, must be replaced, resulting in AMPP being out of market until all repairs are completed.

The emergency conditions were affirmed by the City Council at its regular meeting on March 18, 2025. Pursuant to the Colton Municipal Code 3.08.130 (A), a report on the emergency and work performed shall be provided at the next regular meeting of the City Council, and then at every meeting thereafter.

ISSUES/ANALYSIS

9 Packet Pg. 382
Staff Report to the Mayor and City Council
Emergency Condition - Agua Mansa Power Plant
May 6, 2025

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With AMPP out of the market, the power plant remains unavailable to be called upon to support the City’s energy needs in addition to the broader California Independent System Operator (CAISO) controlled SP 15 market. Based upon staff analysis of replacement energy and energy related products, the immediate cost exposure is $6,300,000 in addition to the replacement costs for the bus work, which is estimated at $1,100,000 for a total unplanned forced outage cost of $7,400,000. This analysis to market exposure assumes the repairs can be made and AMPP is placed back into market on, or before July 31, 2025.

Should repairs extend beyond July 31, 2025 , and AMPP remain s out of market, the financial liability to the Electric Utility will grow exponentially , not only in energy and related products, but also in potential fines levied by the CAISO due to an unplanned forced outage condition.

Conversely, if staff can complete repairs and return AMPP to market ahead of the July 31, 2025 date, the Electric Utility will realize the benefits of market cost avoidance.

Given the significant financial exposure to the City , the City Manager’s Office has issued an emergency declaration and directed staff to effectuate repairs in the most responsible and economic manner possible. To accomplish this, the City has invoked Colton Municipal Code

3.08.130 (A), dispatching with the formal budding requirements and executing all necessary agreements to complete repairs and restore AMPP to dispatchable status.

FISCAL IMPACTS

Sufficient appropriations are available in Fiscal Year 2024 -2025 adopted budget in Electric Utility Fund Agua Mansa Power Plant Capital Account Number 520-8000-8009-4930-0107-000.

ALTERNATIVES

Provide alternative direction to staff.
9 Packet Pg. 383

ITEM NO. 10

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHAD BLAIS,
SUBJECT: APPROVE AND ADOPT A RESOLUTION TO APPROVE LIST OF PROJECT FOR FISCAL YEAR 2025/2026 ROAD REPAIR AND
ACCOUNTABILITY ACT OF 2017 (SB-1); RESOLUTION NO. R-27- 25 RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Approve Resolution No. R-27-25 (Exhibit A) adopting the List of Projects for FY 25-26 funded by SB-1: Road Repair and Accountability Act of 2017.

BACKGROUND

On April 28, 2017 , the Governor signed Senate Bill (SB) 1 (Beall, Chapter 5, Statutes of 2017), which is known as the Road Repair and Accountability Act of 2017 known as SB -1, to address basic road maintenance, rehabilitation and critical safety needs on both the state highway and local streets and road systems. The 2016 California Statewide Local Streets and Roads Needs Assessment found that majority of the City’s streets and roads are in an at -risk/poor condition and this revenue will help us increase the overall quality of our road system and over the next decade will bring our streets and roads into good condition. SB-1 increases per gallon fuel excise taxes, diesel fuel sales taxes and vehicle registration fees. A percentage of the Road Maintenance and Rehabilitation Account (RMRA) funding will be apportioned by formula to eligible cities and counties pursuant to Streets and Highways Code (SHC) Section 2032(h) for basic road maintenance, rehabilitation, and critical safety projects on the local streets and roads system.

ISSUES/ANALYSIS

10 Packet Pg. 384
Staff Report to the Mayor and City Council
Project List - Road Repair and Accountability Act of 2017 (SB-1) May 6, 2025

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Streets and Highways Code (SHC) Section 2032.5(a) articulates the general intent of the legislation that recipients of RMRA funding be held accountable for the efficient investment of public funds to maintain local streets and roads and are accountable to the people through performance goals that are tracked and reported.

Pursuant to SHC Section 2030(a), the objective of the Local Streets and Roads Program is to address deferred maintenance on the local streets and roads system through the prioritization and delivery of basic road maintenance and rehabilitation projects as well as critical safety projects.

Cities and counties receiving RMRA funds must comply with all relevant federal and state laws, regulations, policies, and procedures. The main requirement for the program is the submittal of the list of projects to the California Transportation Commission (CTC) prior to receiving an apportionment of RMRA funds from the Controller in a fiscal year. All projects proposed to receive funding must be included in a city or county budget that is adopted by the applicable City Council or County Board of Supervisors at a regular public meeting. The list of projects is intended to cover, at a minimum, the applicable fiscal year. Project information for future fiscal years can be included and can be updated as needed prior to submittal to the CTC. Any update on project list requires City Council approval.

Below is the list of proposed streets for funding by SB -1 for Fiscal Year 25 -26. Also shown is the project limit and corresponding Pavement Condition Index (PCI) rating of these streets:

Project Description/Location Budget PCI
1 Pavement Rehabilitation: Glenwood Ave. – Westwood
St. to Wild Canyon Dr. $ 98,007 52
2 Pavement Rehabilitation: Westwood St. – Myrtlewood
Ave. to Laurelwood Ave. $106,700 52,61
3 Pavement Rehabilitation: Agua Mansa Rd. (south side
only) – 0.26 mi. west of Rancho Ave. to Walmart Dist.

Center
$127,050 54
4 Pavement Rehabilitation: Riverside Ave. (northbound
only) – M. Bustamante to Bridge $133,650 34
5 Pavement Rehabilitation: Rancho Ave. – Valley Blvd. – I-10 WB on-off ramps $24,750 61
6 Pavement Rehabilitation: G St. – Rancho Ave. to West
City limit $111,073 42
7 Pavement Rehabilitation: 10th St. – M St. to North end $60,926 53,54 8 Pavement Rehabilitation: Fogg St. – Rancho Ave. to 8th St. $192,966 29,35,39,42
9 Pavement Rehabilitation: 8th St. – Fogg St. to Congress St. $118,187 39
10 Pavement Rehabilitation: J St. – 3rd St. to Pennsylvania $78,645 46,43 10 Packet Pg. 385
Staff Report to the Mayor and City Council
Project List - Road Repair and Accountability Act of 2017 (SB-1) May 6, 2025

Page 3 ends

Ave.
11 Pavement Rehabilitation: N St. – 9th St. to 12th St. $171,179 50 12 Pavement Rehabilitation: Olive St. – Rancho Ave. to City Limit at Grand Ave. $40,838 42
13 Pavement Rehabilitation: Skyview Dr – Mohave St. to
End $146,440 38, 58
Total = $1,410,411

The scope of work for the listed street s include pavement grinding, rubberized asphalt overlay, and pavement striping. The inclusion of these streets was based on the Pavement Management Analysis Report developed by IMS Infrastructure Management Services, Inc. in 2016 for the City of Colton. Recipients of SB-1 funding are required to use a Pavement Management System to develop the SB 1 project list to ensure revenues are being used on the most high -priority and cost-effective projects that also meet the community’s priorities for transportation investment.

Pavement Condition Index (PCI) is a numerical index between 0 and 100 being used to indicate the general condition and distress of a pavement. PCI is rated 0 -100, 100 being best and 0 as worst condition. The descriptive range of the PCI ratings are: 0-25 (Very Poor), 26 -40 (Poor), 41-50 (marginal), 51 -60 (Fair), 61 -70 (Good), 71 -85 (Very Good) and 86 -100 (Excellent).

Pavement distress includes but not limited to cracking, bumps, sags, potholes, joint reflections and exposed aggregates. The average PCI of the City’s road network (total of 141.5 miles) is 65.

The national average PCI rating is 60-65.

The projected SB -1 expenditures for the City of Colton for FY 25 -26 is $1, 410,411. This submittal is for the ninth year of SB -1 funding. The City of Colton’s Public Works Department manages compliance with RMRA requirements for eligibility and reporting. The City is in compliance on all previous submittals and reporting.

FISCAL IMPACTS

The total cost of listed streets for FY 25 -26 is $1, 410,411. Appropriations requests for the FY 25-26 Road Repair and Accountability Act of 2017 (SB -1) Projects are included in the proposed FY 25-26 Capital Improvement Project (CIP) budget.

ALTERNATIVES

1. Provide alternative direction to staff.

ATTACHMENT

1. Exhibit A- Resolution SB 1 List of Streets for FY25-26 10 Packet Pg. 386

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RESOLUTION NO. R-27-25

RESOLUTION ADOPTING A LIST OF PROJECTS FOR FISCAL YEAR
2025/2026 FUNDED BY SB -1: THE ROAD REPAIR AND
ACCOUNTABILITY ACT OF 2017

WHEREAS, the City of Colton is a municipal corporation duly organized and existing pursuant to the Constitution and laws of the State of California (“City”); and,

WHEREAS, Senate Bill 1 (SB 1), the Road Repair and Accountability Act of 2017 (Chapter 5, Statutes of 2017) was passed by the Legislature and Signed into law by the Governor in April 2017 in order to address the significant multi -modal transportation funding shortfalls statewide; and,

WHEREAS, SB 1 includes accountability and transparency provisions that will ensure the residents of our City are aware of the projects proposed for funding in our community and which projects have been completed each fiscal year; and,

WHEREAS, the City must adopt a list of all projects proposed to receive funding from the Road Maintenance and Rehabilitation Account (RMRA), created by SB -1, in the City budget, which must include a description and the location of each proposed project, a proposed schedule for the project’s completion, and the estimated useful life of the improvement; and,

WHEREAS, the City will receive an estimated $1, 410,411 in RMRA funding in Fiscal Year 2025/2026 from SB 1; and,

WHEREAS, this is the ninth year in which the City is receiving SB-1 funding and will enable the City to continue essential road maintenance and rehabilitation projects, safety improvements, repairing and replacing aging bridges, and increasing access and mobility options for the traveling public that would not have otherw ise been possible without SB 1; and,

WHEREAS, the City used a Pavement Management System to develop the SB- 1 project list to ensure revenues are being used on the most high -priority and cost - effective projects that also meet the communities’ priorities for transportation investment; and,

WHEREAS, the funding from SB -1 will help the City maintain and rehabilitate streets/roads, bridges and active transportation infrastructure throughout the City this year and other similar projects into the future; and,

WHEREAS, the 2022 California Statewide Local Streets and Roads Needs Assessment found that the majority of the City’s streets and roads are in an at-risk/poor condition and this revenue will help the City increase the overall quality of road system and stabilize the average statewide local pavement condition of streets and roads; and,

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WHEREAS, maintaining and preserving the local street and road system in good condition will reduce driving times and traffic congestion, improve bicycle safety, and make the pedestrian experience safer and more appealing, which leads to reduce vehicle emissions helping the State achieve its air quality and greenhouse gas emissions reduction goals; and,

WHEREAS, the SB-1 project list and overall investment in our local streets and roads infrastructure with a focus on basic maintenance and safety, investing in complete streets infrastructure, and using cutting -edge technology, materials and practices, will have significant positive co-benefits statewide.

NOW THEREFORE, THE CITY COUNCIL OF THE CITY OF COLTON DOES HEREBY RESOLVE AS FOLLOWS:

Section 1 The Recital preceding in this Resolution are true and correct and are incorporated into this Resolution by reference.

Section 2 The City Council authorizes the adoption of the following List of Streets for Fiscal Year 202 5/2026 Pavement Rehabilitation Project to be funded by Road Maintenance and Rehabilitation Account (SB-1) revenues include:

Project 1: SB-1 Funded FY 2025/2026 Street Rehabilitation Project:

a. Glenwood Ave. – Westwood St. to Wild Canyon Dr.– $98,007 - asphalt grind and overlay, striping; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

b. Westwood St. (Myrtlewood Ave. to Laurelwood Ave.) - $106,700 – asphalt grind and overlay, striping ; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

c. Agua Mansa Rd. (0.26 west of Rancho Ave. to Walmart Distribution Center .) - $127,050 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

d. Riverside Ave. – northbound only (M. Bustamante Pkwy to Bridge ) – $133,650 - asphalt grind and overlay, striping ; estimated useful life - 10 to 15 years); estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

e. Rancho Ave. (Valley Blvd. to I -10 WB on-ramp) – $24,750 – asphalt grind and overlay, striping and traffic loops; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

f. G St. (Rancho Ave. to west city limit ) - $111,073 - asphalt grind and overlay, striping; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and

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project construction completion by June 2026.

g. 10th St. (M St. to north end ) - $60,926 – asphalt grind and overlay, striping ; estimated useful life - 10 to 15 years – estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

h. Fogg St. (Rancho Ave. to 8th St.) - $192,966 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years ; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

i. 8th St. (Fogg St. to Congress St.) - $118,187 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years ; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

j. J St. (3rd St. to Pennsylvania St.) - $78,645 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years ; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

k. N St. (9th St. to 12th St.) - $171,179 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

l. Olive St. (Rancho Ave. to City Limit at Grant Ave.) - $40,838 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years ; estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

m. Skyview Dr. (Mohave St. to end) - $146,440 – asphalt grind and overlay, striping; estimated useful life - 10 to 15 years estimated start of design (preparation of project plans, specifications, and estimates) by Sept. 1, 2025, and project construction completion by June 2026.

PASSED, APPROVED AND ADOPTED THIS 6th DAY OF MAY 2025.

__________________________
FRANK J. NAVARRO
Mayor

ATTEST:

__________________________________

ISAAC T. SUCHIL
City Clerk

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Attachment: Exhibit A- Resolution SB 1 List of Streets for FY25-26 [Revision 2] (4901 : Project List - Road Repair and Accountability Act of 2017

ITEM NO. 11

STAFF REPORT

DATE: MAY 6, 2025
TO: HONORABLE MAYOR AND CITY COUNCIL MEMBERS
FROM: BILL SMITH, CITY MANAGER
PREPARED BY: CHARLES BERRY, ELECTRIC UTILITY DIRECTOR
SUBJECT: APPROVE PURCHASE OF 130VDC BATTERY BANK AND
CHARGER FROM AMERICAN POWER SYSTEMS, LLC.

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Approve the purchase of a battery bank and charger from American Power Systems, LLC for $53,757.30 (sales tax included), in accordance with Colton Municipal Code 3.08.080(C) and

3.08.120.

BACKGROUND

The Colton Electric Utility (CEU) uses 130V DC battery banks and charging systems to provide uninterrupted power supply to protection and control devices at each of its 5 electric substations and 1 switchyard. The normal life expectancy of batteries and charging systems is approximately 10 years. Hub’s existing battery bank was in stalled in 2010, and the charger was installed in 2005, which are both now beyond their useful life and require replacement.

ISSUES/ANALYSIS

On November 25, 2024, Hub’s battery bank experienced voltage instability due to failing battery cells, resulting in substantial battery bank degradation. CE U staff were able to secure provisional batteries for system continuity while procurement of a replacement battery bank and charger could be completed. CE U staff recommends replacing the Valve Regulated Lead -Acid (VRLA) batteries with Nickel Cadmium (NiCad) to increase capacity and life cycle of the battery bank. As the battery and charging system at the Hub Substation are at the end of their useful life, it is necessary to replace them with a robust system to prevent damage to critical substation equipment and to maintain system reliability. 11 Packet Pg. 390
Staff Report to the Mayor and City Council
Purchase - American Power Systems, LLC
May 6, 2025

Page 2 ends

In accordance with Colton Municipal Code 3.08.0 80(C) and 3.08.120, CE U staff received three (3) informal quotations for an upgraded battery bank and charger replacements:

1. Concept Power Inc $57,958.00

2. Stored Energy Systems $53,957.00

3. American Power Systems, LLC $51,632.00

Staff recommends that the City Council approve purchase of items from American Power Systems, LLC.

FISCAL IMPACTS

Sufficient appropriations are available for the purchase in the adopted FY2024-25 budget in Electric Utility Fund Substation Division Capital Improvement Budget Account Number 520 - 8000-8003-3890-0107-000.

ALTERNATIVES

1. Provide alternative direction to staff.

ATTACHMENT

1. Alcad-Brochure-0212

2. APS_Quote_70489 (7) Nicad and Charger 20250408 4-7-2025

3. ATevo Battery Charger Hindle

4. LFS020224CEU-Rev 4-HUB-125V Replacement-Nicad Battery-Charger a

5. MKI_SENS_Charger_Nicad_Flooded_VRLA_Q02523_6_20250305 a 11 Packet Pg. 391
VTX 2.2 S
February 2012
Maintenance-free
Ni-Cd batteries
Vantex

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Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
Effect of temperature on lifetime
Percentage of + 25°C (+ 77°F) lifetime
Temperature
°C
100
90 80
70 60
50 40
30 20
10 0
55504540353025
°F131122113104958677
Nickel-cadmium Lead-acid
2 Vantex New Generation
Your first choice for peace of mind
Alcad – providing you
with reliable batteries for
stationary applications
Since the start of the 20th Century
we’ve been working alongside our
clients – companies at the forefront
of their industries - to provide well-
established Ni-Cd battery solutions.

Our world-class batteries offer
optimum security and availability for
stationary applications including power
backup, engine starting and bulk
energy storage.

The Alcad ethos is to strive to be the
best at what we do. Our R&D teams
respond pro-actively to evolving
technologies and streamline our
manufacturing processes, assuring
customers benefit from the highest
quality products.

Alcad’s fully integrated, worldwide
service gives professional support and
guidance right from your project’s
inception, through to supply of the
batteries, installation, professional
training and end of life recycling.

Vantex New Generation gives you complete peace
of mind and long life – including operation at high
temperatures
Alcad’s proven Ni-Cd technology has set the standard in industry for battery performance in challenging environments. Our batteries are renowned for their high performance and reliability, with clients assured of long battery life with no risk of sudden death failure.

Vantex New Generation improves on this impressive track-record by providing a service life of over 20 years at + 25°C [+ 77°C]. Even at temperatures up to + 35°C [+ 95°F], battery life drops by only 20%, as opposed to a 50% fall for a lead-acid battery.

11.a
Packet Pg. 393
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
3 Vantex New Generation
Advanced technology for challenging industrial applications Vantex New Generation:

The maintenance-free(*)
solution for stationary
applications
Alcad’s most recent innovations have
brought improved dependability to the
world of industrial batteries. The latest
Ni-Cd pocket plate technology offers
maintenance-free(*) operation, making
Vantex New Generation the ideal
backup power supply.

Important features include its low
pressure flame-arresting vent,
enhanced electrical performance
and improved chargeability. Vantex
New Generation batteries deliver
exceptional performance for optimal
TCO (Total Cost of Ownership).

Vantex New Generation:

Essential support for vital
systems
When you need a power backup
system you can trust, you need Vantex
New Generation.

Our batteries are the essential
component in power backup systems
across the following industries:
• Oil and gas exploration
• Utilities
• Manufacturing and production
Losing mains power is not a problem
for systems with Vantex backup. Our
batteries provide a crucial power
supply to deliver continuity of mission-
critical loads, expedite safe shutdown
processes, bridge to standby power
and safeguard computer data.

Our batteries are frequently used as
power backup for:
• UPS
• Substation switchgear
• Process control systems
• Emergency lighting
• Fire alarms
• Security systems
(*) The term maintenance-free means that
no addition of water is necessary during the
lifetime of the product, when following Alcad’s
recommended operating conditions.

11.a
Packet Pg. 394
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
4 Vantex New Generation
Providing optimum, maintenance-free(*) performance
Maintenance-free(*) design
keeps running costs down
Vantex’s new state-of-the-art
design concept gives our customers
maintenance-free(*) batteries.
• No need to add water throughout
the service life of the battery
(following Alcad’s recommended
operating conditions – from
- 20°C (- 4°F) to + 40°C (+ 104°F),
at 1.43 V/cell with temperature
compensation).
• Minimal servicing is required with
only preventative maintenance
needed.
• Water use and gas emissions are
reduced due to the high level of gas
recombination of more than 90% –
far beyond the requirements of
IEC 62259.
• Vantex is supplied with a new type
of low pressure flame-arresting
vent – one that works as a valve
regulated vent.

Increased efficiency
optimizes battery life cost
Vantex New Generation has had a
performance upgrade that puts it
well ahead of the original Vantex.

Installers can now select a specific
battery that fits individual operational
requirements, reducing primary
purchase costs.
• Our latest design has enhanced
electrical performance by up to 10%
under relevant discharge times,
enabling a smaller capacity battery.
• Bringing batteries into service is a
straightforward procedure. Even
after six months of storage, the
battery commissioning is easy and
simple. It can be performed with any
commercial charger.

Fast battery charging
reduces downtime
• Quick and simple charging, inside
a narrow voltage window, leads
to good availability with minimal
downtime.
• Single or two-level charging regimes
are available:
− Single level charge
• 1.43 ± 0.01 V/cell
− Two level charge
• Float level: 1.43 ± 0.01 V/cell
• High level: 1.45 ± 0.01 V/cell
• 95% capacity is available, even at
+ 40°C (+ 104°F), after a constant
voltage charge at 1.43 V/cell for
15 hours with an available charge
current of 0.1 C5A.
(*) The term maintenance-free means that
no addition of water is necessary during the
lifetime of the product, when following Alcad’s
recommended operating conditions.

11.a
Packet Pg. 395
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
Available capacity after constant voltage charge
Available charge current 0.1 C5A or 0.2 C5A for L type cell % of the rated capacity
Charging time (hours)
100
80 60
40 20
0 30 352520151050

1.43 V per cell
at + 20°C (+ 68°F) 0.1C 5

1.45 V per cell
at + 20°C (+ 68°F) 0.1C 5

1.45 V per cell
at + 20°C (+ 68°F) 0.2C 5
Available capacity after constant voltage charge
Available charge current 0.1C5A for M type cell
% of the rated capacity
Charging time (hours)
100
80 60
40 20
0 30 352520151050

1.43 V per cell
at + 40°C (+ 104°F)

1.43 V per cell
at + 20°C (+ 68°F)
Vantex New Generation VTX1 L
L type cell
Range of 34 cells
15 – 1700 Ah
For low rate discharges over long periods
between 1 and 100 hours
Vantex New Generation VTX1 M
M type cell
Range of 38 cells
8 – 1330 Ah
For varied loads with low and high discharge rates,
between 30 minutes and 3 hours
5 A battery you can trust
in the most challenging
operating conditions
When safety is of paramount
importance, Vantex New Generation
batteries offer complete reliability, any
time, anywhere.
• Our unique Ni-Cd electrochemistry
works in conjunction with the
tried and tested Alcad pocket plate
design to give you absolute peace
of mind.
• Vantex batteries are an enduring
option with a lifetime service of over
20 years at + 25°C (+ 77°F).
• Strong build quality cuts out the risk
of sudden death failure.
• Vantex provides exceptional
performance combined with a long
service life in temperatures up to
+ 40°C (+ 104°F), and tolerates
- 40°C (- 40°F) to + 70°C (+ 158°F)
for short durations.

11.a
Packet Pg. 396
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
6 Vantex New Generation
A simple approach: our modular system
allows versatile block configurations
Our straightforward design promotes
smooth handling, fitting and
operation.
• All batteries arrive filled with
electrolyte and ready charged.
• The batteries have a long storage
period of up to two years in normal
conditions, and can be stored at
elevated temperatures in certain
circumstances.
• Up to ten cells can be configured
into single integrated blocks
connected in series.
• Adaptable block configuration
allows for quick and simple
installation.

Low pressure
flame-arresting vent
Terminal pillars beneath
terminal covers in line with
EN 50272-2 / IEC 60485-2
(safety) with IP2 level
Plate group bus bar
Plate tab
Polypropylene cell container
Pocket plate
Polypropylene fibrous
separators
Vantex New Generation construction features
Cells are welded together into a block,
up to a maximum of ten cells, subject
to cell size and type

11.a
Packet Pg. 397
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
7 Adaptable block configurations
With single pole bolts
With 2-6 bolts per pole, crosswise mounted on racks
With double pole bolts
L(4)
L(2)
VTX1 L 15-62, VTX1 L 95, VTX1 L 140-280
VTX1 M 8-48, VTX1 M 75-220
VTX1 L 515-560 VTX1 L 610-840
VTX1 M 490-640
VTX1 L 890-1120
VTX1 M 690-885
VTX1 L 1220-1400
VTX1 M 935-1030
VTX1 L 1500-1700
VTX1 M 1130-1330
VTX1 L 325-370
VTX1 M 245-445
VTX1 L 15-62
VTX1 M 8-48
VTX1 L 75, VTX1 L 110
VTX1 M 65
L(5)
L(1)
L(3)
L(6)
L(1)
L(4)
L(7)L(1)
L(8)
L(1)
L(5)
L(9)
L(6)
L(10)
L(1) L(7)

11.a
Packet Pg. 398
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
Temperature de-rating factors for L type cell
5 hour rate 1 hour rate
De-rating factor
Temperature

1.0 1.2

0.8 0.6

0.4 0.2
30 4020100-10-20
86 10468503214-4
°C
°F
Temperature de-rating factors for M type cell
30 mn rate5 hour rate 1 hour rate
De-rating factor
Temperature
30 4020100-10-20
86 10468503214-4
°C
°F

0.8 0.9

1.0 1.1

0.7 0.6

0.5 0.4
8 Vantex New Generation
The practical choice – straightforward usage and installation Batteries with a wide range of specifications
The capacity of Vantex New Generation batteries extends from 8 – 1700 Ah in a choice of two ranges:
• VTX1 L energy range, optimized for long discharge periods with a relatively low current • VTX1 M medium power range, especially designed for mixed loads with varying current

11.a
Packet Pg. 399
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
9 The Vantex New Generation battery design meets the
highest international quality, safety and environmental standards
Tailored support for
all our customers from
start to finish
Customers around the globe
come to Alcad for the ideal
battery solution for their individual
requirements. Our experienced
stationary battery experts work
on everything from the initial
design through to installation
and commissioning. And our
after-sales support assists with
maintenance, diagnostic services
and end of life recycling. Alcad
also provides battery training
seminars for relevant personnel as
required.

As our customer base grows,
we are continuing to expand
our network of approved service
stations in the Middle East, Asia
and North America, to give the
best possible service, worldwide.

Electrical specifications:
• Certified IEC 62259 – Secondary cells and batteries containing alkaline or other non-acid electrolytes – Nickel-cadmium prismatic secondary single cells with partial gas recombination. Vantex exceeds gas recombination requirements.

Safety:
• Complies with EN 50272-2 / IEC 62485-2 – Safety requirements for secondary batteries and battery installations – Part 2: Stationary batteries – The protective covers for terminals and connectors, the insulated cables are compliant with IP2 level protection against electrical shocks according to safety standard.

Quality:
• ISO 9001 and ISO 14001
• Alcad world class continuous programme
Environment & Recycling:
• Fully recyclable
• RoHS – Despite batteries and accumulators not being within the remit of the RoHS directive, Alcad has taken voluntary steps to ensure that the substances forbidden by RoHS are not present in the battery, except in the electro-chemical core. • REACH – Alcad has agreed internal procedures to conform to the European REACH (Registration, Evaluation, Authorisation and Restriction of Chemical Substances) Regulation.

11.a
Packet Pg. 400
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
10 L type
Capacity Height Width Length per block Approx.
weight
per cell
Internal
resistance
(1)
Cell
connection
bolt per
pole
4 cells 5 cells 6 cells 7 cells 8 cells 9 cells 10 cells C5 Ah mm in mm in mm in mm in mm in mm in mm in mm in mm in kg lb mOhm VTX1 L 15 15 270 10.6 123 4.8 101 3.97 124 4.88 148 5.82 172 6.77 195 7.68 219 8.62 242 9.50 1.10 2.42 12.1 M6 VTX1 L 30 30 270 10.6 123 4.8 143 5.62 177 6.96 211 8.30 245 9.65 279 11.0 313 12.3 347 13.7 1.80 3.96 6.03 M6 VTX1 L 47 47 270 10.6 123 4.8 191 7.51 237 9.33 283 11.1 329 13.0 375 14.8 421 16.6 467 18.4 2.50 5.51 3.85 M6 VTX1 L 62 62 270 10.6 123 4.8 239 9.40 297 11.6 355 13.9 413 16.3 471 18.5 529 20.8 587 23.1 3.20 7.05 2.92 M6 VTX1 L 75 75 270 10.6 123 4.8 329 12.9 409 16.1 490 19.2 571 22.5 ------ 4.30 9.47 2.41 2xM6 VTX1 L 95 95 421 16.6 195 7.7 156 6.14 192 7.55 228 8.97 -------- 4.90 10.8 2.55 M8 VTX1 L 110 110 270 10.6 123 4.8 425 16.7 529 20.8 634 24.9 739 29.1 ------ 5.70 12.5 1.65 2xM6 VTX1 L 140 140 421 16.6 195 7.7 204 8.03 252 9.92 300 11.8 -------- 6.70 14.7 1.73 M10 VTX1 L 185 185 421 16.6 195 7.7 252 9.92 312 12.2 372 14.6 -------- 8.40 18.5 1.31 M10 VTX1 L 235 235 421 16.6 195 7.7 304 11.9 377 14.8 450 17.7 -------- 9.90 21.8 1.03 M10 VTX1 L 280 280 421 16.6 195 7.7 352 13.8 437 17.2 522 20.5 -------- 11.5 25.3 0.86 M10 Vantex New Generation
Cell dimensions and internal resistance - L range
The block length and weight are
determined by the number of cells in
the block. All tabulated dimensions
are maximum values.
(1) Rigid connector included
H
W
L type
Capacity Height Width Length per block Approx.
weight
per cell
Internal
resistance
(1)
Cell
connection
bolt per
pole
1 cell 2 cells 3 cells
C5 Ah mm in mm in mm in mm in mm in kg lb mOhm
VTX1 L 325 325 421 16.6 195 7.7 - - 228 8.97 336 13.2 15.1 33.2 0.74 2xM10 VTX1 L 375 375 421 16.6 195 7.7 - - 252 9.92 372 14.6 16.8 37.0 0.65 2xM10 VTX1 L 420 420 421 16.6 195 7.7 - - 278 10.9 411 16.1 18.3 40.3 0.58 2xM10 VTX1 L 470 470 421 16.6 195 7.7 - - 304 11.9 450 17.7 19.8 43.6 0.51 2xM10 VTX1 L 515 515 405 15.9 195 7.7 171 6.73 ---- 21.4 47.1 0.47 2xM10 VTX1 L 560 560 405 15.9 195 7.7 183 7.20 ---- 23.0 50.7 0.43 2xM10 VTX1 L 610 610 405 15.9 195 7.7 207 8.14 ---- 26.5 58.4 0.40 3xM10 VTX1 L 650 650 405 15.9 195 7.7 219 8.62 ---- 28.2 62.1 0.37 3xM10 VTX1 L 700 700 405 15.9 195 7.7 232 9.13 ---- 29.7 65.4 0.35 3xM10 VTX1 L 750 750 405 15.9 195 7.7 243 9.56 ---- 31.4 69.2 0.32 3xM10 VTX1 L 800 800 405 15.9 195 7.7 256 10.0 ---- 32.9 72.5 0.3 3xM10 VTX1 L 840 840 405 15.9 195 7.7 268 10.5 ---- 34.5 76.0 0.29 3xM10 VTX1 L 890 890 405 15.9 195 7.7 291 11.4 ---- 38.1 83.9 0.27 4xM10 VTX1 L 940 940 405 15.9 195 7.7 304 11.9 ---- 39.6 87.3 0.26 4xM10 VTX1 L 980 980 405 15.9 195 7.7 315 12.4 ---- 41.2 90.8 0.25 4xM10 VTX1 L 1030 1030 405 15.9 195 7.7 327 12.8 ---- 42.9 94.5 0.23 4xM10 VTX1 L 1120 1120 405 15.9 195 7.7 352 13.8 ---- 46.0 101.4 0.22 4xM10 VTX1 L 1220 1220 405 15.9 195 7.7 387 15.2 ---- 51.3 113.0 0.20 5xM10 VTX1 L 1300 1300 405 15.9 195 7.7 412 16.2 ---- 54.4 119.9 0.19 5xM10 VTX1 L 1400 1400 405 15.9 195 7.7 437 17.2 ---- 57.5 126.7 0.17 5xM10 VTX1 L 1500 1500 405 15.9 195 7.7 472 18.5 ---- 62.8 138.4 0.16 6xM10 VTX1 L 1600 1600 405 15.9 195 7.7 497 19.5 ---- 65.9 145.2 0.15 6xM10 VTX1 L 1700 1700 405 15.9 195 7.7 522 20.5 ---- 69.0 152.1 0.14 6xM10 L

11.a
Packet Pg. 401
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Vantex
11 M type
Capacity Height Width Length per block Approx.
weight
per cell
Internal
resistance
(1)
Cell
connection
bolt per
pole
4 cells 5 cells 6 cells 7 cells 8 cells 9 cells 10 cells C5 Ah mm in mm in mm in mm in mm in mm in mm in mm in mm in kg lb mOhm VTX1M 8 8 270 10.6 123 4.8 101 3.97 124 4.88 148 5.82 172 6.77 195 7.68 219 8.62 242 9.53 1.10 2.42 12.5 M6 VTX1M 16 16 270 10.6 123 4.8 123 4.84 152 5.96 181 7.12 210 8.27 239 9.41 268 10.6 297 11.7 1.50 3.30 6.25 M6 VTX1M 24 24 270 10.6 123 4.8 143 5.62 177 6.94 211 8.3 245 9.65 279 10.9 313 12.3 347 13.6 1.80 3.96 4.17 M6 VTX1M 32 32 270 10.6 123 4.8 191 7.51 237 9.31 283 11.1 329 13.0 375 14.8 421 16.6 467 18.4 2.50 5.51 3.13 M6 VTX1M 40 40 270 10.6 123 4.8 239 9.40 297 11.6 355 13.9 413 16.3 471 18.5 529 20.8 587 23.1 3.20 7.05 2.50 M6 VTX1M 48 48 270 10.6 123 4.8 239 9.40 297 11.6 355 13.9 413 16.3 471 18.5 529 20.8 587 23.1 3.30 7.27 2.08 M6 VTX1M 65 65 270 10.6 123 4.8 377 14.8 469 18.4 562 22.1 655 25.8 ------ 5.00 11.0 1.54 2xM6 VTX1M 75 75 421 16.6 195 7.7 156 6.14 192 7.55 228 8.97 -------- 4.90 10.8 1.52 M8 VTX1M 100 100 421 16.6 195 7.7 186 7.32 230 9.03 273 10.7 -------- 6.30 13.8 1.14 M10 VTX1M 125 125 421 16.6 195 7.7 228 8.97 282 11.1 336 13.2 -------- 7.60 16.7 0.91 M10 VTX1M 150 150 421 16.6 195 7.7 252 9.92 312 12.2 372 14.6 -------- 8.40 18.5 0.76 M10 VTX1M 170 170 421 16.6 195 7.7 304 11.9 377 14.8 450 17.7 -------- 9.90 21.8 0.67 M10 VTX1M 195 195 421 16.6 195 7.7 352 13.8 437 17.2 522 20.5 -------- 11.5 25.3 0.58 M10 VTX1M 220 220 421 16.6 195 7.7 352 13.8 437 17.2 522 20.5 -------- 12.0 26.4 0.52 M10 M type
Capacity Height Width Length per block Approx.
weight
per cell
Internal
resistance
(1)
Cell
connection
bolt per
pole
1 cell 2 cells 3 cells
C5 Ah mm in mm in mm in mm in mm in kg lb mOhm
VTX1M 245 245 421 16.6 195 7.7 - - 228 8.67 336 17.2 15.2 33.5 0.47 2xM10 VTX1M 270 270 421 16.6 195 7.7 - - 240 9.44 354 13.9 16.0 35.2 0.42 2xM10 VTX1M 295 295 421 16.6 195 7.7 - - 252 9.92 372 14.6 16.8 37.0 0.39 2xM10 VTX1M 320 320 421 16.6 195 7.7 - - 278 10.9 411 16.1 18.3 40.3 0.36 2xM10 VTX1M 345 345 421 16.6 195 7.7 - - 304 11.9 450 17.7 19.8 43.6 0.33 2xM10 VTX1M 370 370 421 16.6 195 7.7 - - 328 12.9 486 19.1 21.4 47.1 0.31 2xM10 VTX1M 395 395 421 16.6 195 7.7 - - 352 13.8 522 20.5 23.0 50.7 0.29 2xM10 VTX1M 420 420 421 16.6 195 7.7 - - 352 13.8 522 20.5 23.5 51.8 0.27 2xM10 VTX1M 445 445 421 16.6 195 7.7 - - 352 13.8 522 20.5 24.0 52.9 0.26 2xM10 VTX1M 490 490 405 15.9 195 7.7 219 8.62 ---- 28.2 62.1 0.23 3xM10 VTX1M 540 540 405 15.9 195 7.7 243 9.56 ---- 31.4 69.2 0.21 3xM10 VTX1M 590 590 405 15.9 195 7.7 268 10.5 ---- 34.5 76.0 0.19 3xM10 VTX1M 640 640 405 15.9 195 7.7 268 10.5 ---- 35.5 78.2 0.18 3xM10 VTX1M 690 690 405 15.9 195 7.7 304 11.9 ---- 39.6 87.3 0.17 4xM10 VTX1M 740 740 405 15.9 195 7.7 327 12.8 ---- 42.9 94.5 0.15 4xM10 VTX1M 785 785 405 15.9 195 7.7 352 13.8 ---- 46.0 101.4 0.15 4xM10 VTX1M 835 835 405 15.9 195 7.7 340 13.3 ---- 45.9 101.1 0.14 4xM10 VTX1M 885 885 405 15.9 195 7.7 352 13.8 ---- 48.0 105.8 0.13 4xM10 VTX1M 935 935 405 15.9 195 7.7 412 16.2 ---- 54.4 119.9 0.12 5xM10 VTX1M 985 985 405 15.9 195 7.7 437 17.2 ---- 57.5 126.7 0.12 5xM10 VTX1M 1030 1030 405 15.9 195 7.7 412 16.2 ---- 56.4 124.3 0.11 5xM10 VTX1M 1130 1130 405 15.9 195 7.7 497 19.5 ---- 65.9 145.2 0.10 6xM10 VTX1M 1230 1230 405 15.9 195 7.7 491 19.3 ---- 67.6 149.0 0.09 6xM10 VTX1M 1330 1330 405 15.9 195 7.7 522 20.5 ---- 72.0 158.7 0.09 6xM10 Vantex New Generation
Cell dimensions and internal resistance - M range
The block length and weight are
determined by the number of cells in
the block. All tabulated dimensions
are maximum values.
(1) Rigid connector included
H
W
L

11.a
Packet Pg. 402
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Alcad:

Preserving our planet for the future
Recycling:

Making a difference all over the world
Our environmental commitment:
• Using recycled materials ahead of raw materials
• Consistently cutting emissions from our production facilities • Minimising water consumption
• Reducing fossil fuel usage and CO2 production
• Making provision for battery recycling
We are committed to helping our customers find recycling solutions for depleted batteries. Alcad has long links with collection companies in most EU countries, in North America and all countries where the system can be implemented. Its collection network receives and dispatches customers’ batteries at the end of their lives to fully approved recycling facilities, in compliance with the laws governing trans-boundary waste shipments.

Our network of collection companies conforms to the EU batteries directive. All of our collection locations are listed on our web site. In countries where we have thus far been unable to set up collection sites, we assist our customers in seeking out viable recycling options.

For more information, please get in touch with your Alcad sales representative.

VTX 2.2 S February 2012. Produced by Arthur Associates Limited. Printed in the UK.

Photo credits: Alcad, Fotolia. Data in this document are subject to change without notice and become contractual only after wri tten confirmation by Alcad.

Alcad Limited
Sweden
Telephone: +46 491 68 100
Facsimile: +46 491 68 110
Alcad Sales Offices
United Kingdom
Telephone: +44 1279 772 555
Middle East
Telephone: +357 25 871 816
Facsimile: +357 25 343 542
Asia
Telephone: +65 6 7484 486
Facsimile: +65 6 7484 639
USA
Telephone: +1 203 985 2500
Facsimile: +1 203 985 2539
www.alcad.com

11.a
Packet Pg. 403
Attachment: Alcad-Brochure-0212 (4902 : Purchase - American Power Systems, LLC) Quote Number 70489 Quote Date 04-07-
2025
Nicad 130VDC Charger
Confidential information in this quotation may not to be distributed without written consent

Page 1 of 1 ends

Xavier Rogers
Colton Utility
American Power Systems, LLC is pleased to provide you the following quotation:

Qty Part Number Description Unit Price Total Price Lead Time 1 VRX1L185 x 95 Cells VTX1L185 x 95 cells. (1) string will provide rated capacity of 185AH @ 5hr rate to 1.00vpc end voltage @
20C 19 x VTX1L185-5 (5 cell block) Includes all inter
cell, inter row and inter tier connectors, NoOx grease, cell numbers, and terminal shrouding
$37,430 $37,430 14 Weeks
1 ATEV1130050E240SS
1XXXXXX1
HIndle ATEV-1-130-50 130VDC, 240VAC Single Phase
50A, Battery Eliminator, 5KAIC AC & DC Circuit
Breaker, (1) Aux Alarm Relay Board, Approval Drawings
$8,040 $8,040
1 EQ1USSS00203150 1 Tier 2 Step Seismic Rack Dimensions: 124 L X 29.13 W X 23.62 H
$3,495 $3,495 14 Weeks
1 EAGLE-K-28-33 Eagle, Floor Anchor, KOH NabPills $467 $467 6 Weeks $49,432
Estimated Freight: $2,200.00
Public Safety Communications Products and Services Contract NASPO ValuePoint Contract Holder: Master Agreement 00318 California Participating Agreement: 7-22-70-49-1
Please reference quote number 70489 on your purchase order and you can email your purchase order to [email protected].

Please make your purchase order out to American Power Systems, LLC with a bill to address of 1851 Central Place South Suite 206, Kent, Washington 98030.

Thank you for your time and consideration. If you need any additional information, please feel free to contact me.

Sincerely,
Keana Houston
[email protected]
Quotation Terms:
 Credit terms are subject to approval and periodic review. You can apply for credit here.  Credit card payment is available here . A 3% processing fee will be applied to all credit card payments.  Freight is FOB Origin and pricing is prepaid and added to invoice (unless otherwise agreed upon in writing).  Freight estimates are valid for 7 days.
 Returned or cancelled items are subject to restocking fees.  Lead times are subject to change without notice.
 Sales or use tax may be included in the final invoice in accordance with state laws.  Please provide sales tax resales or exemption certificates with your purchase order.  All other terms are available here .

11.b
Packet Pg. 404
Attachment: APS_Quote_70489 (7) Nicad and Charger 20250408 4-7-2025 (4902 : Purchase - American Power Systems, LLC) AT Series Product
A Tevo Battery Charger
,62

&HUWLƮHG
JF5054-00

11.c
Packet Pg. 405
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC)

T ABLE OF

CONTENTS
10 Introduction
12 Standard Features
14 Options & Accessories
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18 Available Models &
Standard Enclosures
20 ATevo Ordering Code

INTRODUCTION
HindlePower products have been the utility
industry standard for over 50 years. ATevo
continues the legacy of the AT10.1/
AT30 Series battery chargers.

ATevo is designed and manufactured with
the same high quality and reliability you’ve
come to expect from HindlePower.

Complying with both NERC PRC-005 &
TPL-001, ATevo is equipped with powerful
diagnostics to better assess the health
of your charging system, while meeting
the demand for full system reliability.
“the premier choice for
all stationary battery
FKDUJHUVSHFLƮFDWLRQVš
diagnostics to better assess the
of your charging system, while m
the demand for full system reliab

SIMPLE INSTALLATION & SETUP
7KH$7HYR4XLFN6HWXS*XLGHOHDGV\RXWKURXJKƮYHEDVLFVWHSVIURP LQVWDOODWLRQWRFRQƮJXUDWLRQYLDWKH(GLW(QWHUEXWWRQ

EASY STATUS VERIFICATION
(DVLO\NQRZ\RXUV\VWHPŞVFRQGLWLRQZLWK+LQGOH+HDOWK6\VWHPVWDWXVOLJKWV Green, you are good to go. Solid Red, some maintenance is required.

Blinking Red, immediate action is required.

INTUITIVE USER INTERFACE
The graphic LCD screen provides all the information you need with no guess work.

HIGH QUALITY & RELIABILITY
ATevo comes with the same high quality and reliability that you have come to H[SHFWIURP+LQGOH3RZHU(YHU\EDWWHU\FKDUJHULVEDFNHGE\RXUFXVWRPHUVHUYLFH technical support, and dc expertise.
32 11.c
Packet Pg. 406
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC)

UNIVERSAL CONTROL BOARD
The main control board can operate any ATevo battery charger regardless of input and output ratings.

LOCAL & REMOTE VOLTAGE SENSE
Allows the charger to read the battery
terminal voltage.

FILTERING
2XWSXWƮOWHULQJLVHVVHQWLDOZKHQHYHUWKHUHLVD
need for low AC ripple and low noise on the DC
bus for critical loads.

Available Options:

Filter Level 1 - Filtered (standard)
ťDYDLODEOHIRU9PRGHOV

Filter Level 2 - High Filtered (optional)
ťDYDLODEOHIRU9PRGHOV
6SHFLDOP9)LOWHUHGRQEDWWHU\

RSWLRQDO

ťRQO\DYDLODEOHIRU9PRGHOV

CIRCUIT BREAKER PROTECTION
ATevo comes factory equipped with thermal
magnetic or hydraulic magnetic breakers for both
the AC input and DC output. Higher Ampere
Interrupting Capacity (AIC) ratings are available.
5HIHUWR,QSXW&XUUHQW
$DF
&LUFXLW%UHDNHU
Tables:
•
JF5072-01 for a full list of 1PH AIC ratings
• JF5072-03IRUDIXOOOLVWRI3+$,&UDWLQJV

ST ANDARD FEA TURES

GRAPHICAL LCD DISPLAY
ATevo’s easy to use interface provides all the information you need with no guess work. 'HƮQLWLRQVFRQVLVWHQWZLWKVWDQGDUG,(((

SECURITY
Three levels of password protected security prevents unauthorized users from changing any settings on the ATevo battery charger.

CLEAR SAFETY COVER
Clear acrylic protective cover marked with layout and connection diagram covering all internal components (excludes certain larger battery charger enclosures).

EVENT LOGGING
'RQŞWPLVVDWKLQJ$7HYRFDQORJXSWRHYHQWVVXFKDVDODUPVDQGRUSDUDPHWHUFKDQJHV

GROUND FAULT METERING
Standard, digital, zero-center voltmeter alerts users of any imbalance on the dc bus.

DIGITAL ONLINE MANUAL
)XOOPDQXDOLVDYDLODEOHLQERWK(QJOLVKDQG6SDQLVKZLWKHDV\ QR Code access on charger. • High Level Detect
• Low Level Detect
ť5HFWLƮHU2YHUWHPS
• Relay Failure
ť(QGRI'LVFKDUJH
• Current Limit
• Open Battery Alarm
• 3RVLWLYH1HJDWLYH*URXQG)DXOW:DUQLQJ
• 3RVLWLYH1HJDWLYH*URXQG)DXOW&ULWLFDO
• Open DC Output
• 5HFWLƮHU7HPSHUDWXUH6HQVH)DLOXUH
• Alarm Relay Failure
• *URXQG9ROWDJH,PEDODQFH:DUQLQJ
• *URXQG9ROWDJH,PEDODQFH&ULWLFDO
ť+LJK'&9ROWDJH
ť/RZ'&9ROWDJH
ť'&2XWSXW)DLOXUH

ť$&,QSXW)DLOXUH
ť*URXQG)DXOW
ť&RPPRQ$ODUP
• Open DC Breaker
ť2SHQ([WHUQDODQG,QWHUQDO)HHGEDFN
• Ambient Temperature Probe Failure
• DC Short Circuit
• DC Supply Failure
• (TXDOL]H0RGH'LVDEOHG
• High Level Shutdown
• Low AC Shutdown
• Low AC Supply

VXSSOLHGZLWKGLVFUHWH/('LQGLFDWRU
7KH$7HYRDOORZVXVHUVWRFRQƮJXUHWKHFRPPRQDODUPDQGDOVRgroup alarms into high and low priority.

STANDARD ALARMS

SD MEMORY CARD
Included with every ATevo, the SD card allows users to copy data from the event log, save and restore EDWWHU\FKDUJHUFRQƮJXUDWLRQDQGORDGƮUPZDUHXSGDWHV 54 11.c
Packet Pg. 407
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC) ATevo communication options allow users to remotely monitor and control the battery charger using '13/HYHO0RGEXVDQG,(&3URWRFROV5HIHUWR&RPPXQLFDWLRQV0DQXDOJA0102-54.

SERIAL COMMUNICATIONS ADAPTER (1-00
ETHERNET COMMUNICATIONS ADAPTER (1-00
IEC 61850 COMMUNICATIONS ADAPTER (-
-5#

OPTIONS & ACCESSORIES
(DFKDX[LOODU\LQSXWRXWSXWERDUGLVHTXLSSHGZLWK

(--##

BARRIER TYPE ALARM TERMINAL BLOCK
Features a separate molded phenolic terminal block, wired directly to the Auxiliary Alarm Relay PC Board. It allows the user to connect remote alarm wiring with ring or fork type lugs.
(,-##

AUXILIARY ALARM RELAY BOARD
The Auxiliary Alarm Relay Board gives users the ability to monitor and report ATevo status to or from third party equipment.

COMMUNICATIONS

SURJUDPPDEOHDODUPUHOD\V
(4) programmable generic binary inputs
(4) programmable generic analog inputs

AC LIGHTNING ARRESTOR
Recommended for installations with risk of frequent AC surges, such as high HOHYDWLRQVRUVHYHUHZHDWKHU,VLQDFFRUGDQFHZLWK,(((UHTXLUHPHQWV (--0#

COPPER GROUND BUS
2ƬHUVDFRQYHQLHQWPHDQVWRWLHWKH$7HYRWRWKHEXLOGLQJŞVJURXQG (, -0#
NEMA TYPE-2 DRIP SHIELD
Provides a drip shield on the enclosure to protect it from IDOOLQJGLUWDQGRUGULSSLQJZDWHU
(,
-5#
NEMA TYPE-4 ENCLOSURES
$OOZHDWKHUFDELQHWV
ZLOODOVRPHHW1(0$7<3(DQG7<3(

&2168/7
)$&725<

PD\LQFOXGHVHSHUDWHHQFORVXUHGHSHQGLQJRQFKDUJHUVL]H

FORCED LOAD SHARING
Provides for equal load sharing of 2 identical chargers in parallel, allowing for system redundancy.
(--0#
HINDLEHEAL TH+
An electronically enhanced shunt that provides continuous monitoring of open battery status and calculates the anticipated amp-hour remaining in your EDWWHU\RƬHULQJWKHLQGXVWU\ŞVKLJKHVWOHYHORIUHVROXWLRQDQGDFFXUDF\ Refer to document
JF5081-00 for more information.
ť0RXQWHGLQDVHSHUDWHHQFORVXUH
ť,QFOXGHV%DWWHU\&KDUJH'LVFKDUJH0HWHU %DWWHU\'LVFKDUJH$ODUP ť,QFOXGHV7HPSHUDWXUH&RPSHQVDWLRQ %DWWHU\7HPSHUDWXUH$ODUP ť8WLOLW\FRPSOLDQFHZLWK1(5&35& 73/
(--##

TEMPERATURE COMPENSATION & BATTERY TEMPERATURE/ALARM
$GMXVWVWKHGFRXWSXWLQUHVSRQVHWREDWWHU\WHPSHUDWXUHưXFWXDWLRQV &RPSDWLEOHZLWKOHDGDFLGDQG1L&DGW\SHEDWWHULHV

'LVSOD\VEDWWHU\WHPSHUDWXUHDODUPRQFKDUJHU/&'VFUHHQ (--0#

INTERNAL COATINGS
)XQJXVSURRƮQJDQWLVWDWLFDQG3&%FRQIRUPDO (-- PCB Conformal
(,-
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Anti-Static
(,
-50
Style-5054
(--00
)XQJXV3URRƮQJ

RELAY RACK MOUNTING
$YDLODEOHIRU6W\OHDQG6W\OHHQFORVXUHV7KHVHEUDFNHWVDOORZ PRXQWLQJLQWRVWDQGDUG(,$
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-5#

FLOOR STANDS
$OORZVIRUưRRUPRXQWLQJRI6W\OHDQG6W\OHHQFORVXUHV

WALL MOUNTING BRACKETS
$OORZIRUZDOOPRXQWLQJRIưRRUPRXQWHG6W\OHHQFORVXUHV (,-##

LOCKING PROVISIONS
Provide extra security by physically locking the front door. (,-0# Padlock
(,-1#
Keylock
76 11.c
Packet Pg. 408
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC)

HEAT SHRINK WIRE MARKERS
Provides the additional durability of heat shrink wire markers on the ends of each wire which correspond to the wire numbers on the charger wiring diagram.

VOLTAGE AND CURRENT TRANSDUCERS
7UDQVPLWVP$9GF9GFDQDORJRXWSXWVIRU

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V
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V
PHDVXUHPHQWV

AC METERING
'LVSOD\VLQSXWYROWDJH
9DF
LQSXWFXUUHQW
$DF
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on the battery charger’s digital LCD screen.

FAN CONTROL CONTACTOR
0RXQWHGLQDVHSDUDWH1(0$HQFORVXUHWKLVDFFHVVRU\SURYLGHVD relay contact to activate a battery installation vent or exhaust fan when the charger is in equalize.

AC CIRCUIT BREAKER AUXILIARY SWITCH
Generates alarm when AC circuit breaker is open.
(DC Circuit Breaker Auxiliary Switch is standard)
(--1#
(--04

TOUCH UP PAINT
R]ERWWOHRI$16,JUD\WRXFKXSSDLQW

CUSTOM COLORS
$OO$7HYRHQFORVXUHVIHDWXUHDQ$16,JUD\HSR[\SRZGHUFRDWƮQLVK &XVWRPFRORURSWLRQVDUHDYDLODEOHXSRQUHTXHVW3OHDVHSURYLGHHLWKHU$16, 306RU5$/FRORUGHVLUHG
&2168/7
)$&725<

CABINET HEATER
Provides for anti-condensation heating of the battery charger cabinet. (--0#

CIRCUIT BREAKER/DOOR INTERLOCKS
An added measure of protection that allows the operator to open the battery charger door only when the ac and dc breakers are open. (,-0#

INSECT/RODENT/SNAKE SCREENING
Provides an added protective screen device that inhibits the entrance of LQVHFWVUHSWLOHVDQGVPDOODQLPDOVLQD1(0$RU1(0$HQFORVXUH (--02
(--##
9GF
(--##
9DF
(-
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Adc
(--##
Aac
(--2#
10Adc
(--
20Adc
(--##
(,-00

AC INPUT
Code Input Voltage:

9DFDQGPXOWLWDSLQSXWVQRWDYDLODEOHIRU
certain single phase units, and all three-phase units
Input Voltage Tolerance:
+10%, -12%
Input Frequency Tolerance:

(ƱFLHQF\

W\SLFDOIRU9GFDWORDG

ENVIRONMENTAL

DC OUTPUT
120 9+]
9+]
240 9+]
9+]
9+]
220 9+]
9+]
9+]
07 +]
• Operating ambient temperature -10 °C to
r&ZRGHUDWLQJ
ť2SHUDWLQJDOWLWXGHIW
P

DERYHVHDOHYHOZRGHUDWLQJ
ť5HODWLYHKXPLGLW\WR

ZRFRQGHQVDWLRQ

ť$XGLEOHQRLVHOHVVWKDQG%$DWDQ\
point 5ft (1.5m) from any vertical
surface of enclosure
ť6WDQGDUG,(((

VXSHUFHGHV1(0$3(

ť6WDQGDUGV8/ 8/
• Standard CSA 22.2
ť6WDQGDUG,((($16,&

• Standard FCC Part 15 Subpart J Class A
ť6HLVPLFTXDOLƮHG,(((
&%& ,%&
ť+LQGOH3RZHU6WDQGDUG\HDU:DUUDQW\

(refer to document JF5001-00)

SAFETY & ACCEPTANCE
Voltage Ratings:
DQG9GFQRPLQDO
Current Ratings:
3+XQLWVDYDLODEOHIURP$
3+XQLWVDYDLODEOHIURP$$
(refer to next page for available charger output
ratings)
Continuous Rating:
110% rated current at maximum equalize
voltage at -10 to 50°C
Transient Rating:
3HU,(((VWG
Current Limit Adjustment Range:
50% to 110 % rated output
Voltage Regulation:
+0.25% for line, load, and temp. variations

UHJXODWLRQDWH[WHQGHGHTXDOL]HYROWDJHVPD\QRWPHHW Electrical Noise:
G%UQF
Ripple:
9GF
ť)LOWHU/HYHO)LOWHUHG9UPV
ť)LOWHU/HYHO+LJK)LOWHUHGP9UPV

9GF
ť)LOWHU/HYHO)LOWHUHG9UPV
ť)LOWHU/HYHO+LJK)LOWHUHGP9UPV

ť6SHFLDOP9UPV)LOWHUHGRQ9EDWWHU\
9GF
ť)LOWHUHG/HYHOP9UPV

)LOWHU/HYHOHTXLYDOHQWWR1(0$3(ƮOWHUHGRXWSXW

)LOWHU/HYHOHTXLYDOHQWWR1(0$3(EDWWHU\HOLPLQDWRUƮOWHU Surge Withstand Capability:
'HVLJQHGWRPHHW,((($16,&
D

SPECIFICA TIONS
Standard Drawings &
Operating Instructions
98 11.c
Packet Pg. 409
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC) ( ) + L =
A V AILABLE MODELS & ST ANDARD ENCLOSURES (Single Phase Inputs)

DC OUTPUT RATINGS

VOLTS AMPERES
Enclosure
Style
Approximate
Weights (lbs.(kg))
Heat Loss
Watts (BTU/hr)
249GF
489GF
1309GF
2609GF
6 5054 121 (55) 33 (111)
12 5054 121 (55) 60 (204)
16 5054 132 (60) 78 (265)
20 5054 138 (62) 96 (327)
25 5054 138 (62) 118 (404)
30 5054 147 (66) 141 (481)
40 5054 149 (67) 186 (635)
50 5054 177 (80) 231 (789)
75 5070 282 (128) 344 (1174)
100 5070 317 (143) 457 (1558)
6 5054 121 (55) 42 (144)
12 5054 135 (61) 79 (268)
16 5054 157 (71) 103 (352)
20 5054 175 (79) 128 (436)
25 5054 175 (79) 158 (548)
30 5054 181 (82) 189 (644)
40 5054 198 (90) 250 (852)
50 5054 204 (92) 311 (1061)
75 5070 321 (146) 463 (1582)
100 5070 398 (178) 616 (2103)
6 5054 146 (67) 71 (243)
12 5054 186 (84) 137 (467)
16 5054 211 (96) 181 (617)
20 5054 235 (107) 224 (766)
25 5054 235 (107) 279 (953)
30 5054 241 (109) 334 (1140)
40 5070 341 (155) 443 (1513)
50 5070 384 (174) 553 (1887)
75 5070 422 (192) 826 (2821)
6 5054 199 (90) 120 (411)
12 5054 227 (103) 235 (803)
16 5070 380 (172) 312 (1064)
25 5070 420 (190) 484 (1652)
Ah = Ampere hours removed
5 5HFKDUJHIDFWRU
3E
RU
1L&G

L = Additional standing load
t = Recharge time in hours
5070
5054

HOW TO SIZE YOUR BATTERY CHARGER

6LPSOLƮHG)RUPXOD

( ) + L =
Ah x 1.R
t
Continuous Charger
Output Rating
50 5070 232 (105) 231 (789)
75 5070 251 (114) 344 (1174)
100 5070 269 (122) 457 (1558)
125 5030 392 (178) 569 (1943)
150 5030 413 (187) 682 (2328)
200 5030 479 (217) 908 (3098)
250 5030 658 (298) 1133 (3868)
300 5030 670 (304) 1359 (4638)
400 163 1150 (522) 1810 (6178)
500 163 1300 (590) 2261 (7717)
600 163 1530 (694) 2712 (9257)
800 198 2020 (916) 3614 (12336)
1000 198 2440 (1107) 4516 (15416)
50 5070 257 (117) 311 (1061)
75 5070 305 (138) 463 (1582)
100 5070 327 (148) 616 (2103)
125 5030 461 (209) 769 (2624)
150 5030 471 (214) 921 (3145)
200 5030 535 (243) 1227 (4187)
250 5030 750 (340) 1532 (5229)
300 5030 816 (370) 1837 (6272)
400 163 1100 (499) 2448 (8356)
500 163 1350 (612) 3058 (10440)
600 198 1600 (726) 3669 (12524)
800 198 2020 (916) 4890 (16693)
1000 198 2400 (1089) 6111 (20861)
25 5070 261 (118) 279 (953)
30 5070 261 (118) 334 (1140)
40 5070 300 (136) 443 (1513)
50 5070 333 (151) 553 (1887)
75 5070 407 (184) 826 (2821)
100 5030 629 (285) 1100 (3755)
125 5030 661 (300) 1376 (4690)
150 5030 663 (301) 1647 (5624)
200 5030 746 (338) 2195 ( 7492)
250 163 1130 (513) 2742 (9360)
300 163 1330 (603) 3289 (11229)
400 163 1580 (717) 4384 (14965)
500 198 2150 (975) 5478 (18702)
600 198 2650 (1202) 6573 (22439)
800 198 3250 (1474) 8762 (29912)
16 5070 344 (156) 312 (1064)
25 5070 372 (168) 484 (1652)
50 5030 683 (309) 963 (3286)
75 5030 725 (329) 1441 (4920)
100 5030 819 (371) 1920 (6553)
150 163 1319 (598) 2877 (9820)
200 163 1502 (681) 3834 (13088)
300 198 2323 (1053) 5748 (19622)
400 198 2428 (1101) 7662 (26156)

DC OUTPUT RATINGS

VOLTS AMPERES
Enclosure
Style
Approximate
Weights
(lbs.(kg))
Heat Loss
watts (BTU/hr)
249GF
489GF
1309GF
2609GF
5070
5030
163
198
A V AILABLE MODELS & ST ANDARD ENCLOSURES (Three Phase Inputs) 1110

11.c
Packet Pg. 410
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC)

A TEVO ORDERING CODE
1 130 025 E 240 S S X X XXX X G1

BCDEFGHJKLMNPQR
ATEV

9GFRQO\DYDLODEOHZLWK/HYHOƮOWHU

5HIHUWR-)IRUDYDLODEOHDFLQSXWVYROWDJHVDQGVSHFLƮFN$,&UDWLQJVIRUHDFKEUHDNHURSWLRQ

0XOWLWDSLQSXWRQO\DYDLODEOHRQVLQJOHSKDVHXQLWV$RUOHVVLQHQFORVXUH 1 Single Phase
Three Phase
024 9GF
9GF
9GF
9GF
$GF $GF 012 12 Adc 150 150 Adc $GF $GF 020 20 Adc 250 250 Adc 025 $GF$GF $GF $GF 040 40 Adc 500 500 Adc 050 $GF$GF $GF $GF 100 100 Adc 1k0 1000 Adc F Level 1
( /HYHO
S 96SHFLDO)LOWHULQJ
120 9+]
9+]
240 +]
+]
+]
220 9+]
9+]
9+]
07 +]

B Number of input phases
C
Nominal DC Output
Voltage
D
Nominal DC Output
Current
(refer to page 3-4)
E DC Output Filtering
F AC Input Supply Voltage**

A ATEV

DESCRIPTION CODE FEATURE
6$03/(&2'( S Standard AIC
0 0HGLXP$,&
H High AIC
8 8OWLPDWH$,&
S Standard AIC
0 0HGLXP$,&
H High AIC
8 8OWLPDWH$,&
X 1R$X[,2%RDUG6XSSOLHG
1 2QH$X[,2%RDUG
2 7ZR$X[,2%RDUG
7KUHH$X[,2%RDUG
&RQVXOW)DFWRU\

4 )RXU$X[,2%RDUG
&RQVXOW)DFWRU\

A 2QH$X[,2%RDUGZ%DUULHU7HUPLQDO%ORFNV
B 7ZR$X[,2%RDUGZ%DUULHU7HUPLQDO%ORFNV
C 7KUHH$X[,2%RDUGZ%DUULHU7HUPLQDO%ORFNV
&RQVXOW)DFWRU\

D )RXU$X[,2%RDUGZ%DUULHU7HUPLQDO%ORFNV
&RQVXOW)DFWRU\

X 1R5HPRWH&RPPXQLFDWLRQV6XSSOLHG
1 6HULDO&RPPXQLFDWLRQV0RGXOH
2 (WKHUQHW&RPPXQLFDWLRQV0RGXOH
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4 ,(&&RPPXQLFDWLRQV0RGXOH
C Custom Communications (Consult Factory)
X 6WDQGDUG,QWHUQDO&8$/&RPSUHVVLRQ%R[/XJ6XSSOLHG
G Copper Ground Bus Bar Supplied
L AC Input Lightning Arrestor Supplied
B Both Ground Bus (G) and Lightning Arrestor (L) Supplied 1 1(0$7\SH
6WDQGDUG

2 1(0$7\SH'ULS6KLHOG0RXQWHGWR6WDQGDUG1(0$7\SH(QFORVXUH 4 6SHFLDO1(0$7\SH

:DWHU3URRI&DELQHW
9HQWHG )DQ&RROHG

G AC Input Protection
****
H DC Output Protection
****
J
Auxiliary I/O
PC Boards
(refer
K
Remote
Communications
L,M
N,P Factory Use Only
Q
Site Wiring
Protection
R Enclosure Type
'(6&5,37,21 &2'( )($785(

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11.c
Packet Pg. 411
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC) HindlePower , Inc.
6DLQW-RKQ6WUHHW
(DVWRQ3$
www.hindlepowerinc.com

-)5HY&

11.c
Packet Pg. 412
Attachment: ATevo Battery Charger Hindle (4902 : Purchase - American Power Systems, LLC) Phone
Cell
Email
Reference:

Equipment Part Number Product description Qty. /
System
Net Cost
each
Net Cost /
System
No. of
Systems Totals Notes / Comments
Nickel Cadmium
Battery System
BATTERY 185
A/H - Nicad
Nickel Cadmium - 95 cells
185 A/h @ 5 hr. rate to 1.10
VPC @ 77F.
95 $361.00 $34,295.00 1 $34,295.00 VLA - Lead time 14 to 16 working Weeks
Certified Seismic
Battery Rack
EQ2ULSS002
024001
2-Tier/2-Step: Dimensions L
100" x W 34" x H 68" 1 $4,240.00 $4,240.00 1 $4,240.00 VLA - Lead time 14 to 16 working Weeks
Spill Containment UL Spill
Containment
Lead Acid spill containment
System, P34-100RL-N 1 $2,473.00 $2,473.00 1 $2,473.00 VLA - Lead time 14 to 16 working Weeks
Freight Freight
Estimate
Packing, Shipping and
handling 1 $5,926.00 $5,926.00 1 $5,926.00 Freight Est. at current fuel & surcharges
Sub Total $46,934.00 $46,934.00
LFS020224CEU-Rev 4-HUB-125V Replacement - Nicad Battery + Charger.

Colton, CA 92324 [email protected]
HBU Substation - Supply and Delivery Only - Optional A & B - Flooded Nickel Cadmium (Nicad), 2 Tier 2 Step Battery rack inclucing spill conatinment. Nominal 125 VDC @ (A) 185 A/H & (B) 138 A/H : Life Expectancy 25 Years. - Battery Charger Replacement - ATEVO 130V 50 Amp, Battery Eliminator Filtering, (100mVrms off battery), Specifications as previously quoted.

Pricing excluding Tax - Delivered
Date: Tuesday, March 18, 2025
Quote No:

Quoted by: Leopold Franz Sternberg
Company: Colton Electric Utility 909-370-6195
Attention: Mr. Xavier Rogers 909-370-6195
Address: 150 South 10th Street
City State, Zip:

Replacement Systems, VRLA TO Nickel Cadmium (A) Performance match Concept Power Inc. 9107 WEST RUSSELL ROAD
Suite 100
(We Rectify AC & Backup DC) Las Vegas, NV 89148-1233
Phone: 714-779-1076
Cell : 714-553-9383
Email: [email protected]

11.d
Packet Pg. 413
Attachment: LFS020224CEU-Rev 4-HUB-125V Replacement-Nicad Battery-Charger a (4902 : Purchase - Equipment Part Number Product description Qty. /
System
Net Cost
each
Net Cost /
System
No. of
Systems Totals Notes / Comments
Nickel Cadmium
Battery System
BATTERY 138
A/H - Nicad
Nickel Cadmium - 95 cells
138 A/h @ 5 hr. rate to 1.10
VPC @ 77F.
95 $299.00 $28,405.00 1 $28,405.00 VLA - Lead time 14 to 16 working Weeks
Certified Seismic
Battery Rack
EQ2ULSS002
016501
2-Tier/2-Step: Dimensions L
70" x W 34" x H 68" 1 $4,156.00 $4,156.00 1 $4,156.00 VLA - Lead time 14 to 16 working Weeks
Spill Containment UL Spill
Containment
Lead Acid spill containment
System, P34-70RL-N 1 $2,473.00 $2,473.00 1 $2,473.00 VLA - Lead time 14 to 16 working Weeks
Freight Freight
Estimate
Packing, Shipping and
handling 1 $5,926.00 $5,926.00 1 $5,926.00 Freight Est. at current fuel & surcharges
Sub Total $40,960.00 $40,960.00
Equipment Part Number Product description Qty. /
System
Net Cost
each
Net Cost /
System
No. of
Systems Totals Notes / Comments
Battery Charger
ATEV1130050
E240SS1XXX
XXG1
130 Volt DC 50 Amp
Eliminator Charger 1 $9,130.00 $9,130.00 1 $9,130.00
Lead time 10 to 12
Weeks, Subject to sale
of existing components
Sub Total $9,130.00 $9,130.00
Freight Freight
Estimate
Packing, Shipping and
handling 1 $1,894.00 $1,894.00 1 $1,894.00 Freight Est. at current fuel & surcharges
Sub Total $11,024.00
HUB - Replacement System, Battery Charger 130 Volt DC - 50 Amp.

Replacement Systems, VRLA TO Nickel Cadmium - (B) Calculated according to estimated load profile.

Pricing excluding Tax - Delivered
Pricing excluding Tax
Pricing excluding Tax - Delivered

11.d
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Attachment: LFS020224CEU-Rev 4-HUB-125V Replacement-Nicad Battery-Charger a (4902 : Purchase - Equipment Part Number Product description Qty. /
System
Net Cost
each
Net Cost /
System
No. of
Systems Totals Notes / Comments
Hindle Health -
Battery Charger
EJ5178-00
Hindle Health
On discharge, capacity
utilization 1 $1,334.00 $1,334.00 1 $1,334.00
Lead time 10 to 12
Weeks, Subject to sale
of existing components
Temp Battery VRLA 10 x 12 Volt 100A/H 1 $3,870.00 $3,870.00 1 $3,870.00 Loan delivered.

On-Site Support
and final testing On Site On Site Support during
installation, final testing. 1 $3,800.00 $3,800.00 1 $3,800.00 Not NETA Certified.

Sub Total $9,004.00 $9,004.00

8. Pricing is based on current costs and does not include Tariff, On Charges or Surcharges imposed on imported goods.

4. Standard Manufacturer’s Warranty apply.

5. Payment terms are 30 days net.

2. Purchase Orders should be made out to Concept Power Inc. and emailed to - [email protected]

3. Delivery is 16 to 18 working weeks ARO ex-factory, please allow 7 to 10 days freight to Southern California. deliveries quoted are subject to prior sale of existing stock or manufacturing materials.

6. Local & on-site installation supervision, testing and reports are not NETA certified.

7. Battery and System Load Tests are not included unless specifically quoted for.

Terms & Conditions.

1. Prices are net and firm for 30 days from date hereof, for delivery within 6 months ARO, excluding local taxes.

Optional Extras
Pricing excluding Tax

11.d
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Attachment: LFS020224CEU-Rev 4-HUB-125V Replacement-Nicad Battery-Charger a (4902 : Purchase -

Quotation

Please make orders to:

Stored Energy Systems
C/O Matzinger-Keegan, Inc

Send Purchase Orders to:

[email protected]

Inside Support Technical Sales/Support
[email protected] [email protected]
Isabel Elvira Stephanie Montoya
949-852-1006 310-422-7569

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[Type here] [Type here] Page 1 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

1840 Industrial Circle Longmont, CO, 80501
(303) 678-7500
*Pricing is valid for 60 days from proposal date: 03/04/25. *Lead Time will be confirmed at time of order. Current lead time as of quote date: Varies by Option ARO. -
VRLA Option - LT: 13-15 weeks ARO

Part No. Description Qty Price Each Subtotal
Q120035ZL512C EnerGenius IQ
120: DC Output Voltage: 120 VDC
035: Output Current: 35 ADC
Z: AC Input Voltage: 208/230-240 V, 60 Hz (> 3.4 KW output power), single phase
L: Agency Marks: C-UL 1012 listed (60 Hz units)
512: Feature Package: Eliminator package: Standard input breaker, standard ﬁlter and lower ripple ﬁlter
120 V Eliminator Output Filtering: 30 mV ripple ﬁlter with battery or 100 mV without battery
10 kAIC Input Breaker
C: Alarms/Communication: 7 Form C alarms (30V/2A), 1 Form C alarm (120VAC/5A)
LCD alarm display, one (1) programmable Summary form C
contact (2 ADC at 30 VDC) and seven (7) programmable Form C contacts (2 ADC at 30 VDC) and one (1) Form C alarm (5 Amps AC at 120 VAC) to alarm on issues such as AC Fail, charger fail, low DC voltage, high DC voltage, ground fault positive or negative, battery check fail
Mounting/Additional Features: Wall mount, free-standing available with part number 209399 (Q2 only)
Output Breaker Rating is 10 kAIC

SENS EnerGenius® IQ2 Filtered battery charger, fully automatic Dual microprocessor controlled
1 $7,998.00

$7,998.00

Date 03/04/25 Quote # Q02523.6
Reference Q02523.5 SENS Contact:

Greg Walther
[email protected]
410-220-5644

Local Sales Rep:

Matzinger-Keegan, Inc.

To Xavier Rogers
Company City of Colton
Phone +19093705178
Email [email protected]
Revisions Original Quote Date: 04/05/2024
Revision Reason: Refreshed Pricing and LT.

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[Type here] Page 2 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

Front panel user interface
Digital amp and volt meters
On-board battery checking
Load Share Capable; load kit cable quoted separately
AC and DC breakers
UL/C-UL listed
Seismic certiﬁed to IBC 2006-2021 to an Sds value of 2.50g

23.6 in (W) x 16.1 in (D) x 27.8 in (H), 322 lbs

BMF-2DDMP50-09FR VRLA Battery, EnerSys PowerSafe DDmP, 4V/2 cell, 200 AH, Flame Retardant, UL94-VO/L.O.I. 28%, Number of Cells: 60 total, 2 cells/jar, 30 jars Batteries form an integral rack once assembled.

System is IEEE 693 High Seismic rated.
30 $928.00 $27,840.00
BAT-SP-HWK-21-49 Optional: Battery spill kit, Enviroguard Hawk, 21 in x 49 in, Standard Pillows and SOCS
1 $625.00
BMF-Rental String One 120V string of EnerSys SBS-190 batteries and connectors provided as a temporary string. Price includes (1) month of rental. Additional months of rental will be billed as needed. 1 $1,462.00 $1,462.00
Rental String - Delivery
and Pickup
Delivery and Pickup by EnerSys. No installation is included in the quoted price.
1 $1,847.00 $1,847.00

Total: $ 39,147.00
Total of Optional Items: $ 625.00
-

Flooded Option - LT: 12-14 weeks ARO

$7,998.00

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[Type here] Page 3 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

low DC voltage, high DC voltage, ground fault positive or negative, battery check fail
Mounting/Additional Features: Wall mount, free-standing available with part number 209399 (Q2 only)
Output Breaker Rating is 10 kAIC

SENS EnerGenius® IQ2 Filtered battery charger, fully automatic Dual microprocessor controlled
Front panel user interface
Digital amp and volt meters
On-board battery checking
Load Share Capable; load kit cable quoted separately
AC and DC breakers
UL/C-UL listed
Seismic certiﬁed to IBC 2006-2021 to an Sds value of 2.50g

23.6 in (W) x 16.1 in (D) x 27.8 in (H), 322 lbs

BLA-3CC-9MFR Flooded Lead Acid Battery, EnerSys PowerSafe, Lead-Calcium Alloy, 6V/3 cell, 200 AH, Flame Retardant, Number of Cells: 60 total, 3 cells/jar, 20 jars
20 $1,251.00 $25,020.00
BR-ECHS2T132AP Battery Rack, 2 Tier, 132" Long, Painted, IEEE 693 High seismic 1 $7,602.00 $7,602.00

BAT-SP-EAGLE-NEW-
LA
Battery spill kit, Enviroguard Eagle, xx in x yy in, Standard Pillows and SOCs
1 $1,864.00 $1,864.00
BMF-Rental String One 120V string of EnerSys SBS-190 batteries and connectors provided as a temporary string. Price includes (1) month of rental. Additional months of rental will be billed as needed. 1 $1,462.00 $1,462.00
Rental String - Delivery
and Pickup
Delivery and Pickup by EnerSys. No installation is included in the quoted price.
1 $1,715.00 $1,715.00

Total: $ 45,661.00

NiCad Option - LT: 28-30 weeks ARO

$7,998.00

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[Type here] Page 4 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

battery or 100 mV without battery
10 kAIC Input Breaker
C: Alarms/Communication: 7 Form C alarms (30V/2A), 1 Form C alarm (120VAC/5A)
LCD alarm display, one (1) programmable Summary form C
contact (2 ADC at 30 VDC) and seven (7) programmable Form C contacts (2 ADC at 30 VDC) and one (1) Form C alarm (5 Amps AC at 120 VAC) to alarm on issues such as AC Fail, charger fail, low DC voltage, high DC voltage, ground fault positive or negative, battery check fail
Mounting/Additional Features: Wall mount, free-standing available with part number 209399 (Q2 only)
Output Breaker Rating is 10 kAIC

23.6 in (W) x 16.1 in (D) x 27.8 in (H), 322 lbs

BNC-VGL205 NiCad Battery, EnerSys PowerSafe, 205Ah 92 $385.00 $35,420.00 BR-
AR12T2SBFC2BP108
Battery Rack, 2-Tier 2-Step, 108" Long, Seismic Zone 4 at ground 1 $7,826.00 $7,826.00

BAT-SP-EAGLE-K-NEW-
NiCd
Battery spill kit, Enviroguard Eagle, xx in x yy in, NiCd Pillows and SOCs
1 $2,713.00 $2,713.00
BMF-Rental String One 120V string of EnerSys SBS-190 batteries and connectors provided as a temporary string. Price includes (1) month of rental. Additional months of rental will be billed as needed. 1 $1,462.00 $1,462.00
Rental String - Delivery
and Pickup
Delivery and Pickup by EnerSys. No installation is included in the quoted price.
1 $1,715.00 $1,715.00

Total: $ 57,134.00

Comments / Notes / Exceptions:
• Please note that no sizing was performed by SENS, as the battery size and charger output were stated in the RFQ email and subsequent follow-up emails.
• The quoted SENS EnerGenius IQ2 will be supplied with SENS’ standard wiring and labeling. • SENS will provide our standard installation manual, marking, and shipping documentation normally supplied with SENS products.
• Any items not quoted to be supplied by others.

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[Type here] Page 5 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

• Anchoring kits provided by others.
• No on-site testing, installation, or commissioning of the quoted items is included in this quotation. • Please note that it is the purchaser’s responsibility to ensure the quoted system meets the requirements of their project.

Sales Tax
The purchaser is liable for sales tax. Sales tax exemptions will only be approved if Stored Energy Systems receives a valid sales tax exemption or resale certificate prior to shipment. Certificate MUST be for the state of product delivery and customer is responsible for supplying new certificate(s) if changes are made to shipping terms. For tax specific questions, please consult your CPA or tax professional.

Shipping FCA Origin, Prepaid and Add

*Unless specifically itemized, pricing does not include Shipping and Handling. Items may drop ship from vendors other than SENS.

Payment Terms: Net 30 with approved credit
Product supplied to stand on the quotation provided.

When Ordering, please include on your PO:
 Part numbers as written on this proposal
 Quote number
 Battery chemistry and number of cells, for configuration

Stationary Battery Shelf-Life Disclosure
All batteries have a shelf life, after which their performance and expected lifetime degrade permanently. The shelf life of lead-acid batteries is approximately six months maximum from date of last charge. The shelf life of filled and charged NiCd batteries is approximately one year from date of last charge. These times are best case and are shorter if the battery is stored at temperatures above room temperature.

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[Type here] Page 6 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

SENS Terms & Conditions of Sale

General
The terms and conditions of sale hereinafter set forth (“Terms”) are expressly made part of the quotation and/or acknowledgement of Stored Energy Systems, a Limited Liability Company (“Seller”). These Terms apply to all sales made by Seller except to the extent the Terms conflict with a Sales Agreement signed by Seller and Purchaser. These Terms apply in lieu of any course of dealing between the parties or usage of trade in the industry. These Terms may in some instances conflict with some of the terms and conditions affixed to the purchase order or other procurement document issued by the Purchaser. In such case, the Terms contained herein shall govern, and acceptance of Purchaser’s order is expressly conditioned upon Purchaser’s acceptance of the Terms herein, irrespective of whether the Purchaser accepts these conditions by a written acknowledgement, by implication, or acceptance and payment of products ordered hereunder. Seller’s failure to object to provisions contained in any communication from Purchaser shall not be deemed a waiver of the provisions herein. Any changes in the Terms contained herein must specifically be agreed to in writing signed by an officer of Seller before becoming binding on either party.

Payment
Domestic terms of payment are net cash in U.S. funds, 30 days from date of invoice upon approved credit, credit card, prepayment via bank wire transfer, and approved letter of credit for orders over $10,000. International terms of payment are 100% prepayment via bank wire transfer in U.S. dollars, credit card, or approved letter of credit for orders over $10,000. In the event that any matter is referred for collection, Buyer will pay any and all costs of collection, including attorneys’ fees. The Seller reserves the right to restrict the terms of payments or to require payment prior to time of shipment, or to cancel or defer any order or any part thereof, whenever, in Seller’s sole opinion, the Buyer’s financial condition or other circumstances do not warrant shipment on the terms originally specified in the contract. All rights of the Seller hereunder are cumulative and are in addition to any and all rights and remedies afforded by the Uniform Commercial Code in effect in the State of Colorado.

Shipment
All prices are FCA Factory or other point of shipment unless otherwise expressly agreed upon by the Seller. Method and route of shipment are at Seller’s discretion. For all other items, and in all instances where Purchaser specifies the method and/or route of shipment, the goods are shipped at Purchaser’s expense, “Shipping and Handling collect.” Dock receipts are the responsibility of the Purchaser.

Identification, Title, And Risk of Loss
Title and risk of loss shall pass to the Purchaser when the goods are placed in the hands of the carrier for shipment.

Loss, Damage, Or Delay
Shipping dates are estimated only and are based on conditions at time of quotation. Unless otherwise agreed in writing by Seller, delivery time is not of the essence. Seller does not accept liability for any loss arising from delay in delivery of products.

Storage
In the event that shipment of the goods is unreasonably delayed because of Purchaser’s unwillingness or inability to accept delivery or because of Purchaser’s request to witness any test, Seller will store the goods and charge Purchaser for the cost of storage, insurance, maintenance of the goods, and other incidental costs.

Taxes, Duties and Licenses: All prices are exclusive of applicable federal, state or local taxes, export duties, or like taxes and duties, unless otherwise expressly provided. Seller shall have no obligation to secure any export license or permit for its products.

Installation and Service
All prices are exclusive of the services of a field service specialist for field installation or services. The charge for such services may be negotiated and included in the price or purchased on a separate purchase order at existing rates. If Purchaser installs the goods, it shall do so in accordance with instructions provided by Seller.

Returns
All sales are final. No goods may be returned without the prior written consent of the Seller. If Seller elects to accept a return for credit, a restocking fee per the following table will apply, and Seller will issue a Return Material Authorization Number (RMA). Goods returned without such RMA or with shipping and handling due, or without payment of the restocking fee will be refused.

Restocking Fee Schedule
Product Family % sales
price
NRG, MicroGenius 2 20%
EnerGenius IQ, BBS, MicroGenius S2, S4 45%
EnerGenius DC, MicroCab 70%
PowerCab, PowerRack, and all other products No returns

Changes and Revisions
Seller reserves the right to make revisions and changes in its goods and assumes no obligation to incorporate these changes in earlier models. The terms and conditions contained herein and the prices contained in Seller’s price sheets and quotations are subject to change without notice.

Limited Warranty
Seller warrants its products to be free from defects in material and workmanship under normal use and service for the following periods from the date of shipment:

EnerGenius IQ & DC, MicroGenius S4 60 months
NRG, MicroGenius 2, S2 36 months
MicroGenius LE 12 months
DC Systems 24 months system +
standard period for
embedded chargers
Battery Monitoring 12 months
Spare Parts 6 months
Other SENS-built products 24 months

Warranty on products resold by SENS is per the original manufacturer’s warranty. Seller’s sole obligation under this warranty shall be limited either to replace or repair defective goods or to refund the purchase price, at Seller’s option, after inspection at Seller’s plant verifies the claim. There are no other warranties which extend beyond the description of this limited warranty, and to the full extent permitted by law, any and all implied warranties, including implied warranties of merchantability or fitness for a particular purpose or arising from any course of dealing or usage or trade, are hereby expressly disclaimed and excluded, as well as all other obligations or liabilities of seller.

Repudiation
If the Purchaser repudiates the contract in whole or in part prior to shipment of the goods, then, notwithstanding any other remedy available to the Seller, the Seller may identify to the contract any conforming finished goods in the Seller’s possession or control at the time the Seller learns of the repudiation, or if the goods at such time are unfinished the Seller may either complete the manufacture and wholly identify the goods to the contract or cease manufacture and resell for scrap or salvage value or proceed in any other

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[Type here] Page 7 of 7
All content contained herein is Proprietary and Confidential to Stored Energy Systems, LLC and may only be used for the intended audience and purpose. Sharing of any content herein with additional parties is strictly prohibited and may only be authorized in writing by Stored Energy Systems, LLC.

reasonable manner, including, but not limited to, the imposition of a re- stocking fee.

Release for Manufacture
Purchase orders received, processed, and acknowledged requiring approval of engineering drawings, or other form of literature, prior to “release for manufacture,” or stipulating a “hold for approval” for any reason, are deemed to be special in their content. Receipt of said approved drawings, or literature, or confirmation of approval of same, is considered release to manufacture.

Approval of said drawings, or release to manufacture, by the company issuing said purchase order, or its representative, is considered acceptance of the technical capability of said equipment to meet its needs and acceptance of the responsibility of all cost of processing, engineering and manufacture of said order and entitles Seller to the full selling price of all items included on said purchase order or addendums to same.

Force Majure
Seller is not liable for loss, damage, detention, or delay due to causes beyond its reasonable control such as acts of God, acts of Purchaser, acts of civil or military authority, priorities, fires, strikes, floods, epidemics, quarantine restrictions, war, riot, delays in transportation, government restrictions or embargoes, or difficulties in obtaining necessary labor, materials, and manufacturing facilities due to such causes.

Limitation of Liability
Purchaser agrees that seller shall not be liable for any special, incidental, exemplary, indirect or consequential damages including but not limited to loss of goodwill, even if seller shall have been advised of the possibility of such potential loss or damage, arising out of or resulting from the sale, installation or use of any seller product or service or for any other reason. Seller’s total cumulative liability in connection with any occurrence or series of occurrences, whether in contract or tort or otherwise, will not exceed the contractual value of the specific goods or services from which the liability arises.

Governing Law; Venue
All contracts for the purchase of Seller’s products are deemed to be made at Seller’s offices in Longmont, Colorado, and deemed Colorado contracts, and shall be governed by the laws of the State of Colorado in effect on the date of the contract. The parties agree and consent that the appropriate jurisdiction and venue for any legal action based on this Contract shall be in the County of Boulder, State of Colorado.

Export regulations
Purchaser agrees to comply fully with all laws and regulations concerning the purchase and sale of goods. In particular, Buyer agrees to comply with the Export Administration Regulations of the United States in so far as they apply to the sale of goods.

Service
Any Service completion date or Product delivery date specified on the face hereof is approximate and is not a guarantee of a particular day of completion of the Services to be performed hereunder or delivery of the Products, and such dates are based upon prompt receipt of all necessary information. SENS and its affiliates are not liable for damages resulting from any delay or failure to perform the Services as scheduled.

Cancellation requests must be made in writing and accepted by SENS in writing. Completed work and work in progress will be charged at quoted prices.

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ITEM NO. 12

STAFF REPORT

RECOMMENDED ACTION

Staff recommends that the City Council take the following action:

Approve the sole source purchase of Agbay meter lock rings from Inner-Tite, for $148,813.50, in accordance with Colton Municipal Code 3.08.140(b).

BACKGROUND

The Colton Electric Utility (CEU), Substation Division, standardized on the use of Inner-Tite meter lock rings, and in 2009 migrated to the “Agbay” keyed locking mechanism. “Agbay” is a premium security barrel lock patented by Inner -Tite. Inner -Tite has created an exclusive combination (key) used by CEU staff for locking and unlocking meter rings.

A meter lock ring is a consumable item that is routine in its use and is considered a high security locking mechanical device that protects against unauthorized removal of an electric meter . The Inner-Tite meter lock ring is manufactured from heavy -duty carbon steel, “Agbay” that is case hardened to resist cutting, tamper resistant and pick proof, making it ideal for utility applications.

ISSUES/ANALYSIS

As part of the continuing program to change out CE U’s existing electric meters, there has been a contrasting amount of lock rings versus meters purchased. Since 2021, CE U has increased the purchase amount of lock rings to help manage this contrast. Staff is requesting to purchase quantities of meter lock rings to cover the annual purchase and to continue to advance on the backlog of lock ring replacements.
12 Packet Pg. 425
Staff Report to the Mayor and City Council
Purchase - Inner-Tite
May 6, 2025

Page 2 ends

Colton City CouncilMay 6, 2025

Colton City Council
May 6, 2025