Municipal Services Committee
December 9, 2025

AGENDA

MUNICIPAL SERVICES COMMITTEE

REGULAR MEETING NOTICE
DECEMBER 09, 2025
PUBLIC MEETING 4:00 P.M.

MEMBERS
Justin Jones, Chair, District 3
Rick Cole, Councilmember, District 2
Tyron Hampton, Councilmember, District 1
Jason Lyon, Councilmember, District 7
STAFF
David Reyes, General Manager
Lisa Hosey, Assistant City Attorney
Betty Gao, Recording Secretary

MISSION STATEMENT
The City of Pasadena is dedicated to delivering exemplary municipal services, responsive to our entire community and consistent
with our history, culture and unique character.

I
n compliance with the Americans with Disabilities Act of 1990, Assistive Listening Devices are available from the City Clerk’s Office with a 24-hour advance notice.

Please call (626) 744-4124 to request use of a listening device.

Language translation services are available for this meeting by calling (626) 74
4-4124 at least 24 hours in advance.

Habrá servicio de interpretación disponible para éstas juntas llamando al (626) 74
4-4124 por lo menos con 24 horas de anticipación.

I
tems on the agenda may not be called in order listed.

Agendas and supporting documents are available on the Internet at http://ww5.cityofpasadena.net/commissions/city-council-municipal-services-committee/ Materials related to an item on this Agenda submitted to the Municipal Services Committee after distribution of the agenda packet will be posted online and listed as: “Supplemental Agenda Material Received after the Posting of the agenda”.

PUBLIC COMMENT AT THE MUNICIPAL SERVICES COMMITTEE REGULAR MEETING FOR DECEMBER 09, 2025, AT 4:00 P.M. WILL BE ACCEPTED IN- PERSON AND BY VIDEOCONFERENCE/TELECONFERENCE.

Link to City Meeting Policy:
cityofpasadena.net/CityCouncilMeetingPolicy
T
O VIEW A LIVE STREAM OF THE MEETING:
http://pasadena.granicus.com/MediaPlayer.php?publish_id=9 AND
WWW.PASADENAMEDIA.ORG
In order to facilitate public participation at meetings the City will accept public comment in the following manner:

1. Whether participating in-person or virtually at the meeting, members of the public may provide public comment by submitting a speaker card prior to the start of public comment on that item, at the following webpage:
www.cityofpasadena.net/commissions/public-comment/
If a public comment speaker wishes to speak on more than one agenda item, please indicate which items on the online form (multiple item speakers will be handled according to the process posted on the agenda and as specified in the City meeting policy). Public comments are limited to 3 minutes each, and the Chair and Committee may limit this time if reasonable under the circumstances.

2. In-pe rson Meeting Participation: Complete an online speaker card at the following website: www.cityofpasadena.net/commissions/public-c omment/ After submitting a public speaker card, members of the public may attend the meeting in-person by coming to the Pasadena City Council Chamber, Room S249 at City Hall at the date and start-time of the posted meeting.

Virtual Meeting Participation:

For virtual participants, you may attend by connecting
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To participate in public comment for an item and to be recognized to speak, it is r
equired that the speaker login to the meeting using the same name or telephone number used on the Speaker Card form. This will allow City staff to locate and promote the speaker into the meeting when it is time for their public comment.

Participants’ phone calls to the Committee meeting will be recorded as part of the Committee meeting. By staying on the line and making public comment during the Committee meeting by phone, you are agreeing to have your phone call recorded. Following is the connectivity information for virtual participation:

Computer or electronic devices, join the meeting at: cityofpasadena.net/cczoom Telephone only dial-in: 1-669-900-6833, Meeting ID: 161 482 446

3. Speaker Card Help Line: I f a public comment speaker needs assistance in completing a speaker card, please call the City Clerk’s Office at: (626) 744-4124. The help line will open 30 minutes prior to the posted start time of the meeting.

4. Members of the public may submit correspondence of any length prior to the start of the meeting, at the following email address:
c
[email protected]
C
orrespondence will be forwarded to the Committee prior to the start of the meeting, posted online, and made part of the legislative record for the item.

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F YOU NEED A REASONABLE MODIFICATION OR ACCOMMODATION PURSUANT TO THE

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AS SOON AS POSSIBLE AT (626) 744-4124 OR [email protected].

CITY OF PASADENA

SPECIAL MEETING OF

THE MUNICIPAL SERVICES COMMITTEE
DECEMBER 09, 2025
PUBLIC MEETING: 4:00 PM

PASADENA CITY HALL, COUNCIL CHAMBER
100 NORTH GARFIELD AVENUE, ROOM S249
NOT
ICE IS HEREBY GIVEN that the regular meeting of the Municipal Services Committee will be held on Tuesday, December 9, 2025, at 4:00 p.m., to discuss matters on the attached agenda.

Justin Jones, Chair

Municipal Services Committee
I HEREBY CERTIFY that this agenda in its entirety, was posted on the Internet at https://www.cityofpasadena.net/commissions/city-council-municipal-services-committee/ and on the Council Chamber Bulletin Board, Room S249, and the Bulletin Board in the rotunda area; City Hall, 100 North Garfield Avenue, this December 4, 2025, by 6:30 p.m. and that copies hereof were faxed, emailed or delivered to each member of the City Council and to each local newspaper of general circulation, radio or television station requesting notice in writing, all of which recipients are identified on the distribution herein below.

Derrick Airitam
DISTRIBUTION:

MSC Committee Members Central Library General Manager Pasadena Weekly City Council City Clerk Director of Planning and Permitting Pasadena Star-News City Manager Director of Public Works Los Angeles Times Pasadena Now City Attorney Public Information Officer La Opinion Pasadena Journal In compliance with the Americans with Disabilities Act of 1990, listening assistive devices are available from the City Clerk's Office with a 24-hour advance notice.

Please call (626) 744-4124 to request use of a listening device. Language translation services may be requested with 24-hour advance notice.

Habra servicio de interpretacion disponible para estas juntas llamando al (626) 744-4124 por lo menos con 24 horas de anticipación.

SPECIAL MEETING AGENDA

MUNICIPAL SERVICES COMMITTEE
DECEMBER 09, 2025
Public Meeting: 4:00 P.M.

Council Chamber, Pasadena
City Hall 100 North Garfield Avenue, Room S249
The Municipal Services Committee may take action within its authority on any item listed on this agenda as it deems appropriate following consideration and discussion of the matter.

APPROVAL OF MINUTES
October 14, 2025 (Regular Meeting)
October 28, 2025 (Regular Meeting)

1. EL

ECTRIC RATES RECOMMENDATION
Set a date of february 9, 2026, to conduct a public hearing for recommended electric rate adjustments and direct the city attorney’s office to prepare an ordinance amending the light and power rate ordinance and adopt the utility rate resolution.

INFORMATIONAL ONLY
Information only items contain no staff recommendations. The committee may, however, take action within its authority relating to informational items on the agenda as it deems appropriate following consideration and discussion of the matter.

2. UTI

LITY UNDERGROUNDING OVERVIEW
PUBLIC MEETING - 4:00 P.M.

ROLL CALL

PUBLIC COMMENT

ADJOURN

NEW BUSINESS/ACTION ITEMS
1 01 10/14/2025

CITY OF PASADENA

MUNICIPAL SERVICES COMMITTEE MINUTES

PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
CITY HALL COUNCIL CHAMBER – S249
OCTOBER 14, 2025

MEETING
OPENING The Chair called the meeting of the Municipal Services Committee to order at 4:07 p.m.

ROLL CALL:

S
taff:

Councilmember Justin Jones, Chair
Councilmember Tyron Hampton (Arrived at 4:11 p.m.)
Councilmember Rick Cole
Councilmember Jason Lyon
David Reyes, General Manager of Water and Power
Joaquin Siques, Director of Transportation
Donson Liu, Engineer
Hy Lao, Associate Engineer
Caroline Monroy, Assistant City Attorney
Betty Gao, Recording Secretary
PUBLIC COMMENT No one appeared for public comment on matters not on the agenda.

APPROVAL OF MINUTES It was moved by Councilmember Cole, seconded by Councilmember Lyon, to approve the minutes of August 26, 2025, September 9, 2025, and September 23, 2025 (cancelled meeting) , as submitted. ( Motion unanimously approved) (Absent: Councilmember Hampton)

NEW BUSINESS LOCAL ROADWAY SAFETY ACTION PLAN
C
ouncilmember Hampton
arrived at 4:11 p.m.

David Reyes, General Manager of Water and Power , and Joaquin Siques, Director of Transportation, provided introductory comments and responded to questions.

The Committee recessed at 4:10 p.m. and reconvened at 4:22 p.m.

Donson Liu, Engineer, summarized the agenda report as part of the PowerPoint presentation on the item, including providing information on safety corridors, injuries statistics, Safe Streets and Roads for All (SS4A), discretionary grant, process of plan, and community input; and responded to questions.

In response to Councilmember Cole’s inquiry related to the project list and scores, Director Siques noted that on Attachment B (of the agenda report): Community Generated Project List and Scores, the individual scores were transposed incorrectly from previous list, but the total score is correct.

Councilmember Hampton expressed concerns with naming the resolution “Establishing a G oal of Zero Roadway F atalities and Reduction of Serious Injuries by 2035” , noting the challenges in achieving such goals. He encouraged staff to focus on streets in the City with frequent collisions and fatalities; and asked staff to provide 2 02 10/14/2025
information on historical collision data in the City . He advocated for speed feedback signs located throughout the City to be updated to “real time” so Pasadena Police Officers are able to access speeding data immediately.

Chair Jones advocated for additional traffic officers on t he streets to reduce speeding in residential areas.

Betty Gao, Recording Secretary, reported that ten letters of correspondence was received by the City Clerk’s Office, which were distributed to the Committee, posted online, and made part of the record for this item.

The following individuals spoke in support of the staff’s recommendation and/or provided other related comments on the matter:

Thomas Priestley, Pasadena resident
Humaira Afzal, Pasadena resident
Jonah Kanner, Pasadena resident
Jeff Cyrulewski , Pasadena resident, expressed concerns with the rushed proposal plan and the lack of community input.

The following individuals expressed concerns with traffic safety and communication outreach, advocated for additional traffic enforcements, and/or provided other related comments on the matter:

Bill MacMullin, Pasadena resident
Ellie MacMullin, Pasadena resident
Councilmember Cole advocated for staff to develop a holistic and strategic safety plan for the City that includes enforcement, outreach and education. He would like the plan to include building a network where people can get around the City safely, as opposed to project by project, grant by grant, or controversy by controversy approach.

Councilmember Cole proposed an amendment to extend the corridor project on Washington B oulevard from Sierra Bonita Ave nue to Allen Avenue.

In response to Councilmember Cole’s comments, Chair Jones stated that holistic planning will be agendized at a future Committee meeting.

Councilmember Lyon thanked staff for the thorough, clear and visual Pasadena Local Roadway Safety Action Plan report. He echoed Councilmember Cole’s comments on the need of a holistic Citywide safety approach. Councilmember Lyon expressed concerns with the proposed plan, which he believes does not fully address safety issues across the City, particularly within the C entral District where collision hot spots are most prominent, and therefore he is unable to the support the plan in its current form. He also noted that the plan may be out of date and not aligned with the current grant funding criteria but reaffirmed his support for pursuing funding opportunities and the goal of zero traffic fatalities. Councilmember Lyon requested staff to include additional East -West Central District project plans and details , and address all twenty safety corridors in the report submitted to the City Council; and recommended amending the language of the report as the 3 03 10/14/2025
description notes a citywide program, which he believes is not correct, but rather the report is a subset of the City’s safety projects.

Councilmember Hampton highlighted safety concerns along Orange Grove B oulevard at Walnut St reet and North Lincoln Avenue; advocated for staff to extend project improvements along North Lincoln Avenue; and emphasized the need for a stronger departmentwide City communication plan. He asked staff to agendize at a future Committee meeting a discussion on a departmentwide city communication plan.

Chair Jones voiced support of Councilmembers Cole and Hampton’s proposed amendments to the Pasadena Local Roadway Safety Action Plan report.

In response to Councilmember Cole’s request for staff to amend the title of the report to “Focused Local Roadway Safety Action Plan”, Mr.

Siques, Director of Transportation, responded that staff understands the Committee direction and will provide language to address the concerns of the Committee.

MOTION: Following discussion, it was moved by Councilmember Cole, seconded by Councilmember Hampton, to approve the staff recommendation , amended to extend the corridor projects on Washington Boulevard and Lincoln Av enue, and forward the item to the City Council for consideration and further discussion.

AYES: Councilmembers Cole, Hampton, Chair Jones
NOES: None
ABSENT: None
ABSTAIN: Councilmember Lyon

CENTRAL DISTRICT TRAFFIC MANAGEMENT
Joaquin Siques, Director of Transportation, provided introductory comments, and Hy Lao, Associate Engineer, summarized the memo as part of the PowerPoint presentation on the item, including providing information on traffic s ignal timing, signal operations, central district coordination, Sydney Coordinated Adaptive Traffic System (SCATS), rail operations, and daily traffic management; with both responding to questions.

Councilmember Lyon spoke on his constituent’s concerns related to the flow of traffic in the City. The general concern is that the traffic flow from east to west is too fast, and the traffic flow from north to south is too slow. He asked staff to adjust the time at red stops on California Boulevard and Hudson Avenue as he believes the wait time on red light is too long; and asked staff to gather data on traffic travel time across the City.

Councilmember Hampton advocated for additional signage in the City for when emergency vehicles are on the road.

Following discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.
4 04 10/14/2025

SEWER SYSTEM MANAGEMENT PLAN - UPDATE
Due to time constraints, on the order of the Chair, and by consensus of the Committee, the above referenced item will be continued to a future Committee meeting.

RECEIVE ANNUAL REPORTS FOR FISCAL YEAR JULY 2024
THROUGH JUNE 2025 AND WORK PLANS FOR FISCAL YEAR
2025-2026 FOR:
a. DESIGN COMMISSION
b. HAHAMONGNA WATERSHED PARK ADVISORY COMMITTEE
c. HISTORIC PRESERVATION COMMISSION
d. HUMAN SERVICES COMMISSION
e. LIBRARY COMMISSION
f. PLANNING COMMISION
Due to time constraints, on the order of the Chair, and by consensus of the Committee, the above referenced items will be continued to a future Committee meeting.

ADJOURNMENT On the order of the Chair, the meeting of the Municipal Services Committee was adjourned at 6:18 p.m.
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
ATTEST:
____
________________
Betty Gao
Recording Secretary
5 01 10/28/2025

CITY OF PASADENA

MUNICIPAL SERVICES COMMITTEE MINUTES

PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
CITY HALL COUNCIL CHAMBER – S249
OCTOBER 28, 2025 MEETING
OPENING The Chair called the meeting of the Municipal Services Committee to order at 4:05 p.m.

ROLL CALL:

S
taff:

Councilmember Justin Jones, Chair
Councilmember Tyron Hampton (Absent)
Councilmember Rick Cole
Councilmember Jason Lyon
David Reyes, General Manager of Water and Power
Greg de Vinck, Director of Public Works
Lynne Chaimowitz, Assistant General Manager of Water and Power Garrett Crawford, Public Works Administrator
Jack Miyamoto, Water Quality Manager
Michael King, Program Coordinator
Lisa Hosey, Assistant City Attorney
Betty Gao, Recording Secretary
PUBLIC COMMENT Cynthia Cannady, representing Pasadena 100 , expressed concerns with the expansion of the Magnolia Power Project Plant owned by Southern California Public Power Authority (SCPPA).

In response to public comment, General Manager Reyes stated that Pasadena Water and Power voted against the project’s expansion.

Cecilia Abramson, Pasadena resident, urged the City to support climate emergency Resolution 9977 goals by exiting the Magnolia Power Project partnership and transitioning off of fossil fuels.

Simon Anuszczyk, Pasadena resident, expressed concerns with the Optimized Strategic Plan (OSP) not aligning with Resolution 9977 ’s goal to source carbon free 100%.

NEW BUSINESS ADOPTION OF THE REVISED ENERGY AND CREDIT RISK

MANAGEMENT POLICY
David Reyes, General Manager of Water and Power , and Lynne Chaimowitz, Assistant General Manager of Water and Power, summarized the agenda report as part of the PowerPoint presentation on the item, including providing information on p olicy framework, risk governance structure, revision background, policy updates, trading limits and authorizations, with both responding to questions.

Councilmember Cole spoke in support of staff’s recommendation with the following amendments:
• The Assistant General Manager to maintain three-month authorization and limit oversight intervals instead of the proposed six-month extension; and
6 02 10/28/2025
• The Committee to receive and review management energy and credit risk reports annually rather than as needed.

Councilmember Lyon praised and thanked staff for their hard work on the policy changes.

Cynthia Cannady, representing Pasadena 100, expressed concerns with the staff report and/or provided other related comments on the matter.

Following discussion, it was moved by Councilmember Cole, seconded by Councilmember Lyon, to approve the staff recommendations amended as detailed above, and forward the item to the City Council for consideration and further discussion. ( Motion unanimously approved) (Absent: Councilmember Hampton)

MASTER STREET TREE PLAN
Greg de Vinck, Director of Public Works, provided introductory comments, and Michael King, Program Coordinator, summarized the staff memo as part of the PowerPoint presentation on the item, including providing information on the City’s street tree plan background, Fairfield Circle Amendment, general amendment, guiding principles, species diversity factors, and tree species list ; with both responding to questions.

In response to Councilmember Cole’s inquiry on shade and canopy, Garret Crawford, Public Works Administrator, stated that detailed canopy coverage will be included in a future urban forestry management plan following adoption of the general amendment, and responded to questions.

Councilmember Cole advocated for a resilient, climate conscious tree plan with additional resources as needed, and expressed frustration with the systemic disconnect between departments and consultant recommendations regarding tree species selection, noting that extensive planning and consultant work has not consistently resulted in the implementation of approved or recommended trees.

Councilmember Lyon shared positive experiences regarding Fairfield Circle Amendment and echoed Councilmember Cole’s comments on strengthening coordination between planning and implementation, ensuring consistency of tree lists across departments, and prioritizing shade and canopy in tree planting. He requested that staff revise the general amendment language to reflect shade and canopy priorities and advocated for minimizing fire-prone tree species Citywide.

Chair Jones echoed Councilmembers Cole and Lyon’s comments on interdepartmental collaboration and the importance of shade and canopy trees. He asked staff to return to the Committee with a plan and maps prioritizing shade and canopy tree expansion, particularly in hotter areas of the City.

Dr. Julianna Delgado, representing Design Commission , voiced concerns on the proposed general amendment and replacing healthy established trees.
7 03 10/28/2025
Lee Wallace, representing West Pasadena Residents’ Association, asked the Committee to support efforts to address fire-prone areas surrounding the Arroyo Seco through tree planning and evacuation measures.

Alan Bair, Pasadena resident, advocated for greater tree species diversity Citywide, repurposing removed trees as mulch, and exploring solar canopies for shade and energy.

Yadi, Pasadena resident, voiced concerns regarding tree planting and called for clear City guidance on tree management and planning.

Following discussion, the Committee asked staff to amend the Master Street Tree Plan to:
• Emphasize shade and canopy trees throughout the City; • Acknowledge that the Master Street Tree Plan is part of a broader Urban Forestry Management Plan;
• Plan for any additional resources needed throughout planni ng and implementation of the plan;
• Reconcile the Master Tree Plan with the City’s specific plans; and
• Consider fire-prone trees Citywide.

Following discussion, it was moved by Councilmember Cole, seconded by Councilmember Lyon, to approve the staff recommendations amended as detailed above, and forward the item to the City Council for consideration and further discussion. ( Motion unanimously approved) (Absent: Councilmember Hampton)

INFORMATION ONLY PREPAID RENEWABLE ENERGY TRANSACTION FOR COST

SAVINGS
David Reyes, General Manager of Water and Power , and Lynne Chaimowitz, Assistant General Manager of Water and Power, summarized the staff memo as part of the PowerPoint presentation on the item, including providing information on the Clean Energy Purchase Contract background, prepay renewable bond, Power Purchase Agreements, and risks and benefits; with both responding to questions.

General Manager Reyes acknowledged and thanked Lisa Hosey, Assistant City Attorney, for her hard work on the item.

Following discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.

PUBLIC HEALTH GOALS
David Reyes, General Manager of Water and Power, and Jack Miyamoto, Water Quality Manager, summarized the staff memo as part of the PowerPoint presentation on the item, including providing information on background of the report, public health goals, cost of treatment, Consumer Confidence Report (CCR), and resources; and responded to questions.
8 04 10/28/2025

Councilmember Cole encouraged staff to develop a more proactive report outlining issues and corresponding solution steps beyond the standard reporting format.

Following discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.

Chair Jones announced that an agenda item regarding the Committee’s meeting start time will be scheduled at a future meeting.

ADJOURNMENT On the order of the Chair, the meeting of the Municipal Services Committee was adjourned at 5:49 p.m.

__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee

ATTEST:

____________________
Betty Gao
Recording Secretary

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40 423357.1
Draft Report | December 1, 2025
Electric Rate Study
Pasadena Water and Power
Pasadena, California
Prepared by:
© 2025 NEWGEN STRATEGIES AND SOLUTIONS, LLC
ATTACHMENT A: Draft Financial Report and Revenue Requirements (NewGen Document)
41 42

Economics | Strategy | Stakeholders | Sustainability PWP_Rate Study Re port_CLIENT DRAFT_12.01.25_Section 2

423357.1
Section 2

REVENUE REQUIREMENTS
Developing the Test Year Revenue Requirement is the first step in the cost of service and rate design process, as shown in Figure 1-1. The Test Year Revenue Requirement for the City of Pasadena’s Light and Power Fund was based on the average expenses for Fiscal Year (“FY”) 2026 through FY 2027 with adjustments for unusual or one-time expenses, the ad opted Capital Improvement Plan (“CIP”), existing debt amortization schedules, projected debt issu ances, and forecasted escalation assumptions and factors. NewGen developed a four-year financial forecast for the Study Period. The average revenue requirement for the first two years was used as the test year revenue requirement and represents all costs that must be recovered through the electric rates. The Test Year Revenue Requirement serves as a basis for determining the overall level of revenue recovery and provides a foundation for the cost of service analysis.

Financial Forecast
The financial forecast includes projections of revenues, expenses, capital spending, debt service, and changes in reserves over the four-year Study Pe riod (FY 2026–FY 2029). Pasadena Water and Power (“PWP” or “the Utility”) received guidance from the ratemaking bo dy, City Council, on July 14, 2025, to establish the Study Period and set rates for a two-year period. To develop the financial forecast, NewGen Strategies and Solutions, LLC (NewGen) utilized the Light and Powe r Fund’s FY 2026 budgeted expenses, load forecast documents, records of operations, customer billing data, and other detailed information and data compiled and provided by PWP. The forecast used the FY 2026 budgeted expenses as the base year in the financial forecast. Any projected non-recurring expenses or revenues were identified and incorporated in the financial forecast, as appropriate.

To forecast expenses through FY 2029, NewGen used multiple escalation and forecast factors. The forecast applied specific inflatio n and customer growth rates to th e baseline FY 2026 budget year data and reviewed each account or group of accounts to select an applicable escalation or inflation rate for the expenses. For Power Supply-related costs, NewGen relied on a detailed forecast and resource plan from PWP that integrated their long-term purchased power agreements, fuel price forecasts, renewable energy credit forecasts, and other proprietary energy market forecasts.

The financial model also provides PWP the capabilit y of evaluating scenarios for future financial performance by changing rates, issuing debt, and calc ulating key performance indicators (“KPIs”). These KPIs for PWP are based on the financial policies, bond covenants, and other financial performance targets set by the Utility and/or City Council. Typically, as a utility best practice, PWP evaluates overall forecasted expenses, revenues, and the resulting KPIs such as the Debt Service Coverage Ra tio (“DSCR”) and level of cash reserves. PWP evaluates varying levels of debt issuance and changes in rates over time to fund the required capital investments, while ensuring it maintains the targeted financial KPIs. These rate and debt recommendations are primarily driven by the increasing capital needs of the Utility and the need to ensure PWP maintains established DSCR and cash reserve levels. 43 Section 2

2-2 PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 Projected Energy Requirements
The forecasted load demand was a key driver in proj ections of expenses and revenues in the financial forecast. PWP developed and supplied the load fore cast. The forecasted re tail electric consumption includes an annual average energy growth rate of 1.3% in the Study Period, which reflects sales to PWP’s retail customers.

Table 2-1
Estimated Energy Requirements During Study Period
FY 2026 FY 2027 FY 2028 FY 2029
PWP Retail Load (MWh) 1,037,516 1,042,651 1,054,593 1,078,494

Financial Forecast Results
The results of PWP’s evaluation of the financial forecast are shown in Table 2-2. As discussed previously, PWP evaluated the overall financial performance to recommend balanced system-wide rate changes and debt issuances in the Study Period. Based on the forecast, the recommended total rate increase or total bill change for the Test Year period is 9.5% in FY 2026 and 9.5% in FY 2027. For the remaining years in the forecasted Study Period, PWP initially forecasts no tota l rate change or total change in bills for FY 2028 and 2029. Future rate changes in FY 2028 and 2029 are initial esti mates based on guidance and may change based on progress, timing, fuel costs, po wer market prices, and execution of the Optimized Strategic Plan.

Table 2-2
Financial Forecast Results
Item
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
O&M Expenses $203,774,257 $215,204,439 $209,252,937 $229,852,057 Debt Service $15,624,250 $18,000,250 $18,780,848 $18,779,473 Capital Paid from Current Earnings (1) $106,015,456 $73,701,937 $99,636,557 $93,648,293 Capital Paid from Low Carbon Fuel Standard and
Undergrounding Fund (2) $8,052,160 $7,604,000 $8,392,000 $5,692,000 Capital Paid from Customers (3) $5,574,406 $5,512,500 $5,512,500 $5,512,500 City Transfer $28,500,000 $29,963,471 $33,034,435 $33,402,912 Other Expenses (Income) ($56,997,751) ($62,870,311) ($54,186,209) ($53,082,907) Revenue Requirement $310,542,778 $287,116,286 $320,423,067 $333,804,327 Debt Issuance Recommendations $0 $50,000,000 $0 $0
Total Rate Change Recommendations (4) 9.5% 9.5% 0.0% 0.0% Projected Revenues at Recommended Rates $249,695,590 $275,286,961 $278,357,598 $314,104,442 Difference (5) ($60,847,188) ($11,829,325) ($42,065,469) ($19,699,885) (1) Capital funded by grants nor grant revenue are included in the financial forecast results. (2) Corresponding revenues for Low Carbon Fuel Standard (“LCFS”) and Underground are included in Other Expenses (Income). (3) Corresponding revenues for capital paid from customers are included in Other Expenses (Income). 44 Financial Forecast

PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 2-3

Table 2-2
Financial Forecast Results
Item
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
(4) Rate changes represent rate changes implemented on January 1st, 2026, and 2027. (5) The difference in the revenues and total expenses is managed by cash reserves. The results of the annual change in cash reserves are summarized later in this section.

The remainder of this section will summarize and desc ribe the key components of the financial forecast results, in addition to quantifying the Test Year Revenue Requirement for FY 2026 and 2027 that will support the rate change recommendations for those ye ars. As discussed previously, the Test Year and recommended rate plan do not include FY 2028 and 2029, as the operating and capital expenses for those years will change and are dependent on future decisions related to the implementation of the OSP.

Operations and Maintenance Expenses
The first step in developing the revenue requirement forecast was the creation of the base year operations and maintenance (“O&M”) expenses. PWP’S historic al data and FY 2026 budget provide the Light and Power Fund O&M expenses. In discussions with PWP management, NewGen selected the detailed FY 2026 budget as the base year in the financial forecast for projections of O&M expenses.

Based on the FY 2026 budget from PWP, NewGen forecasted the O&M costs for the Study Period. In addition to the projected other expenses/revenues (i ncluding interest income, capital contributions, miscellaneous revenues, and sales to other utilities), CIP, debt service projections, and City Transfer, these forecasted O&M expenses supported the eventual de velopment of the Test Year Revenue Requirement.

The Test Year Revenue Requirement includes all costs required to operate the Utility and ensure financial stability for the Electric Utility over the desired period of time the rates are in effect.

O&M Forecast Account Detail
Table 2-3 summarizes the forecasted O&M expenses for the Study Period. NewGen used the average two-year O&M expenses for FY 2026 and 2027 for the Test Year Revenue Requirement as seen in Table 2-

4. 45

Section 2

2-4 PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 Table 2-3
Forecasted O&M Detailed Funds
Account
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
Personnel
General Manager $539,001 $558,136 $577,949 $598,467
Public Benefit Charge $1,491,644 $1,544,597 $1,599,431 $1,656,210 Finance and Administration $3,949,226 $4,089,424 $4,234,598 $4,384,926 Customer Service and Administration $7,337,358 $7,597,834 $7,867,557 $8,146,856 Power Delivery $19,307,534 $19,992,951 $20,702,701 $21,437,647 Power Supply $11,392,208 $11,796,631 $12,215,412 $12,649,059 External Affairs $875,675 $893,189 $911,052 $929,273
Services & Supplies
General Manager $566,813 $578,149 $589,712 $601,506
Public Benefit Charge $9,911,155 $10,109,378 $10,311,566 $10,517,797 Finance and Administration $4,240,328 $4,325,135 $4,411,637 $4,499,870 Customer Service and Administration $2,801,969 $2,858,008 $2,915,169 $2,973,472 Power Delivery $9,801,632 $14,235,765 $14,435,718 $14,639,670 Power Supply $119,848,203 $124,501,244 $115,928,569 $133,821,597 External Affairs $793,902 $809,780 $825,976 $842,495
Internal Service Charge
General Manager $122,761 $127,671 $132,778 $138,089
Public Benefit Charge $300,358 $312,372 $324,867 $337,862 Finance and Administration $1,299,538 $1,351,520 $1,405,580 $1,461,804 Customer Service and Administration $986,850 $1,026,324 $1,067,377 $1,110,072 Power Delivery $4,778,438 $4,969,576 $5,168,359 $5,375,093 Power Supply $1,261,922 $1,312,399 $1,364,895 $1,419,491 External Affairs $162,992 $169,512 $176,292 $183,344
Other Operating Expenses
General Manager $0 $0 $0 $0
Public Benefit Charge $0 $0 $0 $0
Finance and Administration $36,415 $37,143 $37,886 $38,644 Customer Service and Administration $72,835 $74,292 $75,778 $77,293 Power Delivery $1,868,500 $1,905,870 $1,943,987 $1,982,867 Power Supply $27,000 $27,540 $28,091 $28,653
External Affairs $0 $0 $0 $0
Total $203,774,257 $215,204,439 $209,252,937 $229,852,057

46 Financial Forecast

PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 2-5

Table 2-4
O&M Revenue Requirement
Account
Year 1
FY 2026
Year 2
FY 2027
Two-Year
Average
Personnel $44,892,646 $46,472,762 $45,682,704
Services & Supplies $147,964,002 $157,417,459 $152,690,730 Internal Service Charge $8,912,859 $9,269,373 $9,091,116 Other Operating Expenses $2,004,750 $2,044,845 $2,024,798 Total $203,774,257 $215,204,439 $209,489,348

A summary of the key elements of the O&M expenses in addition to other expenses, such as debt service and transfers, are included below.

Power Supply Expenses
Power Supply expenses are the largest portion of th e total O&M expenses and are associated with take or pay contracts (i.e., Intermountain Power Plant, Magnolia Power Plant, Palo Verde Power Plant, and Hoover Hydro Power), purchased power agreements (i.e., numerous renewable energy contracts), resource adequacy costs, and all other purchases to meet system demand. PWP provided the projected power supply costs incorporated into the Study. Additional power supply expenses include PWP labor and other supporting O&M accounts for the power plant, wholesale operations, and power supply management and planning. The tables below summar ize the total power supply expenses for the Study Period and the power supply expenses for the revenue requirement.

Table 2-5
Power Supply Expenses
Item
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
Power Supply
Personnel $11,392,208 $11,796,631 $12,215,412 $12,649,059 Fuel Cost $5,513,608 $6,610,536 $6,651,127 $6,626,018
Purchased Power $102,925,795 $105,078,270 $96,895,814 $114,226,684 Other Power Supply
Expenses $4,287,961 $3,580,699 $3,095,374 $3,709,607
Other Services & Supplies $7,147,839 $9,259,278 $9,314,345 $9,287,940 Internal Service Charge $1,261,922 $1,312,399 $1,364,895 $1,419,491 Total Power Supply O&M $132,529,333 $137,637,814 $129,536,966 $147,918,799

47 Section 2

2-6 PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 Table 2-6
Power Supply Revenue Requirement
Item
Year 1
FY 2026
Year 2
FY 2027
Two-Year
Average
Power Supply
Personnel $11,392,208 $11,796,631 $11,594,420
Fuel Cost $5,513,608 $6,610,536 $6,062,072
Purchased Power $102,925,795 $105,078,270 $104,002,033
Other Power Supply Expenses $4,287,961 $3,580,699 $3,934,330 Other Services & Supplies $7,147,839 $9,259,278 $8,203,558 Internal Service Charge $1,261,922 $1,312,399 $1,287,160 Total Power Supply O&M $132,529,333 $137,637,814 $135,083,574

Transfer to the City General Fund (City Transfer)
The annual contribution for any municipal purpose (“City Transfer”) is defined in the Section 1408 stating, “each fiscal year, the City Council shall transfer from the Light and Power Fund an amount equal to twelve percent (12%) of the gross income of the electric works received during the immediately preceding fiscal year from the sale of electric energy at rates and charges.” In the financial forecast and Test Year Revenue Requirement, the City Transfer forecast was calculated according to the City Charter.

Debt Service
The debt service represents existing and projected debt service. The existing debt service within the Study Period and the Test Year Revenue Requirement includes the three outstanding bond issuances and associated amortization schedules.

For the Study Period, one new debt issuance was forecasted. The new debt issue supports the large CIP plans over the Study Period and Test Year. Key capital projects funded through the debt issuance include major investments in power delivery modernization—su ch as sizing infrastructure for projected load growth from electrification, addressing aging infras tructure, and strengthening system resilience against risks like wildfires. Funding these projects are investments that will serve future generations of customers with substantial asset lives. PWP identified $50 milli on in total debt issuances within the Study Period would be sufficient with the expectation that ra te revenues and cash reserves will fund all other anticipated CIP.

Table 2-7 summarizes the projected debt service for the Electric Utility, and Table 2-8 summarizes the debt service revenue requirement.

48 Fin
ancial Forecast
PW
P_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 2-7 Table 2-7
Electric Debt Service (1)
Item
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
Debt Service
Existing Direct $15,624,250 $15,625,250 $15,620,375 $15,619,000 Future $0 $2,375,000 $3,160,473 $3,160,473
Total $15,624,250 $18,000,250 $18,780,848 $18,779,473
(1) Please note that the total amounts shown in the table may not properly add as shown due to rounding.

Table 2-8
Electric Debt Service Revenue Requirement (1)
Item
Year 1
FY 2026
Year 2
FY 2027
Two-Year
Average
Debt Service
Existing Direct $15,624,250 $15,625,250 $15,624,750
Future
$0 $2,375,000 $1,187,500
Total $15,624,250 $18,000,250 $16,812,250
(1) Please note that the total amounts shown in the table may not properly add as shown due to rounding.

As men
tioned previously, PWP evaluates the financial forecast and possible rate and debt issuance actions by monitoring financial KPIs. By bond covenants, PWP must maintain a minimum 1.5 DSCR. Pasadena Municipal Code 13.04.17513 outlines the Light and Power Fund’s working capital reserves, which includes maintaining a minimum and target reserve equivalent to one year of debt service payments for outstanding bond or credit obligations. Table 2-9 summarizes the DSCR for PWP at the recommended rate increases for FYs 2026 and 2027. The operating expenses shown in Table 2-9 do not include capital paid from rate revenues and cash reserves, which is explained later in this section. 49 Section 2

2-8 PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 Table 2-9
Electric Debt Service Coverage Ratio (1)
Item
Year 1
FY 2026
Year 2
FY 2027
Two-Year
Average
Operating Revenues (2) $303,008,999 $336,542,314 $319,775,657 Operating Expenses $203,774,257 $215,204,439 $209,489,348 Net Revenues Available $99,234,742 $121,337,875 $110,286,308 Debt Service
Existing Direct (3) $15,624,250 $15,625,250 $15,624,750 Future $0 $2,375,000 $1,187,500
Total $15,624,250 $18,000,250 $16,812,250
Debt Service Coverage Ratio (4) 6.4 6.7 6.6
(1) Please note that the total amounts shown in the table may not properly add as shown due to rounding. (2) Operating revenues include retail rate revenues, interest income, and other or miscellaneous revenues. (3) DSCR equals the Net Revenues Available divided by the total Debt Service.

Capital Paid from Current Earnings
The Electric Utility’s capital expenses are identified within the FY 2026 Budget fo ur-year CIP. To finance these capital investments and system upgrades over the Study Period, the Utility plans to utilize a combination of debt, rate revenues, and cash reserves. These projects are most notably the implementation of the advanced metering infrastructure, a software and hardware investment, and the PWP battery energy storage system. These projects ar e critical modernization projects that have been delayed and are time-critical within the Study Period. However, in the absence of rate adjustments, a significant portion of the annual CIP would need to be funded through cash reserves. The average annual capital expenses funded through rate revenues or cash reserves—reflected in FY 2026, FY 2027, and the Test Year Revenue Requirement— to tals $89.9 million. Table 2-10 pres ents the annual capital outlays funded through cash sources over the Study Period, while Table 2-11 summarizes the capital outlays attributed to cash sources in the Test Year.

Table 2-10
Electric Capital Funded with Cash Sources
Item
Year 1
FY 2026
Year 2
FY 2027
Year 3
FY 2028
Year 4
FY 2029
Cash-Funded Capital $106,015,456 $73,701,937 $99,636,557 $93,648,293

50 Revenue Requirement

PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 2-9

Table 2-11
Electric Capital Funded with Cash Sources for Revenue
Requirement
Item
Year 1
FY 2026
Year 2
FY 2027
Two-Year
Average
Cash-Funded Capital $106,015,456 $73,701,937 $89,858,696

Capital funded through grants and contributions in aid of construction (“CI AC”) from customers are excluded from the revenue requirement and COS as they do not contribute to costs that must be recovered in PWP’s rates. All expenses associated with construction in these two categories are independently funded and have no impact on revenue requirement. As such, CIAC is adjusted out of the revenue requirement as seen in Table 2-12.

Other Income and Expenses
Other income and expenses represent miscellaneous no n-operating revenues or expenses that are a net $57.3 million in revenues in the Test Year. This am ount reflects non-operating revenues, which include interest income, grants, charges for internal serv ices, and miscellaneous revenues (e.g., late fees, connection fees, etc.). These net revenues act to reduce the overall revenue requirement and eventual rates paid by PWP customers. Adju stments have been made to other in come to arrive at the Test year Revenue Requirement. Corresponding with the CIAC removal from capital expenses, the CIAC associated revenues are also removed from other income. Ad ditionally, adjustments are made to the revenues associated with the public benefit charge and LCFS as these expenses and revenues be equal in practice.

PWP targets annual public benefit charge and LCFS related expenses to be equal to the revenues generated. After adjustments, these net revenues reduce the overall Test Year Revenue Requirement by $57 million.

Revenue Requirement
There are two primary revenue requirement methodologies employed in the utility industry: the cash basis and the utility basis. The primary differences between the cash basis and the utility basis involve the treatment of depreciation, return on invested capital, and debt service. The cash basis, which is the most common method used by municipalities, includes debt service but excludes depreciation and return on invested capital in the revenue requirement determination. The cash basis focuses on meeting the cash demands of the utility. The utility basis, common ly used by private or for-profit utilities, includes depreciation and return on invested capital, but excludes debt service from the revenue requirement determination.

In this cost of service analysis, NewGen utilized the cash basis as it follows the traditional cash-oriented budgeting practices frequently used by government entities. Furthermore, the cash basis is generally easier to communicate to customers, as it aligns revenue with expenditures.

NewGen developed the Test Year Revenue Requirement for the two-year Study Period, including all costs required to operate the Utility and ensure its financia l stability. The Test Year Revenue Requirement of $259,540,672 is the two-year average of the annual revenue requirements and is shown in Table 2-12. 51 Section 2

2-10 PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 The current rates are insufficient to fully recove r the projected operating and capital costs by approximately $31.6 million.

Table 2-12
Test Year Revenue Requirement (1)
Account 2-Year Average Adjustments Test Year
O&M Expenses (2) $209,489,348 $209,489,348
Debt Service (3) $16,812,250 $16,812,250
Capital Paid from Rates $89,858,696 $89,858,696
Capital Paid from Low Carbon Fuel Standard and
Undergrounding Fund (4) $7,828,080 $7,828,080
Capital Paid from Customers (5) $5,543,453 ($5,543,453) $0 City Transfer $29,231,735 $29,231,735
Other Expenses/(Income) (6) (59,934,031) $2,592,850 ($57,341,181) Application of Reserves ($36,338,257) ($36,338,257)
Revenue Requirement (7) $262,491,275 ($2,950,603) $259,540,672 Test Year Projected Revenues (8) $227,962,131
Over (Under) Recovery of Costs ($31,578,541)
(1) Please note that the total amounts shown in the table may not properly add as shown due to rounding. (2) O&M Expenses exclude non-cash related items such as Depreciation. (3) Debt service reflects the annual total principal and interest payments associated with current and expected new debt financing. (4) Corresponding revenues for Low Carbon Fuel Standard (LCFS) and Underground are included in Other Income. (5) Corresponding revenues to capital paid from customers are included in Other Income. (6) Other Expenses/(Income) include interest income, non-operating expenses, miscellaneous revenues, and non-operating revenues. (7) Please note the 2-year average revenue requirement shown here does not equal the revenue requirements shown in Table 2-2 as Table 2-12 applies the use of cash reserves to reduce the revenue requirement (8) Test Year Projected Revenues assume the current Power Cost Adjustment.

NewGen has included the application of cash reserves to decrease the Test Year Revenue Requirement in Table 2-12. Existing reserves meet and exceed its financial policies and minimums and maintains them after the Test Year period and use of a portion of the reserves.

Reserves
Unrestricted cash reserves serve multiple purposes, including providing working capital, funding capital projects, mitigating market and price volatility risks to customers, and supporting the Utility’s overall cash flow management. The annual balances and contributions to or use of reserves, assuming PWP does not adjust base rates, are shown in Table 2-13.

If PWP does not implement rate increases, the estimated annual shortfall of $31.5 million in the revenue requirement will further draw down the cash reserv es beyond the levels already planned and shown in Table 2-12. The estimated reserve balance as of July 1, 2025, is $409 million or 741 days of cash on hand.

Without any rate increases, PWP’s cash reserve balance is projected to decline by $137 million over the Study Period, decreasing from $409 million to $271 million. 52 Reserves

PWP_Rate Study Report_CLIENT DRAFT_12.01.25_Section 2 2-11

Table 2-13
Electric Cash Reserve Balances – No Rate Increases (1)

Year 1
FY 2026
Year 2
FY 2027
Fund Balance – BOY $408,829,565 $327,709,874
Deposits from Earnings (2) $38,522,331 $30,914,198
Withdrawals (Capital & Operating) ($119,642,022) ($86,818,437) Fund Balance – EOY $327,709,874 $271,805,635
Days Cash on Hand BOY
741

564
Days Cash on Hand EOY
595

469
(1) Please note that the total amounts shown in the table may not properly add as shown due to rounding.
(2) Deposits from earnings represent the operating revenues less operating expenses, City Transfer, and debt service.

If the proposed total rate increases of 9.5% for both FY 2026 and FY 2027 are implemented, the projected ending balance in FY 2027 increases from $271 milli on to $336 million, equivalent to 578 days cash on hand. The cash reserve balances, resulting from the proposed systemwide rate adjustments, are consistent with industry standards and provide PWP flexibility and financial stability to support future operating and capital requirements. Additionally, the reserves offer the ability to manage uncertainties related to construction timelines, project schedul es, and financing costs, including interest rate fluctuations. Beyond these functions, the cash reserves serve multiple purposes within the Utility, such as providing working capital, stabilizing rates to reduce volatility, and funding capital improvements.

PWP has a working capital policy reflected in Pa sadena Municipal Code Chapter 13.04.175 which establishes the “Working Capital targets to be the sum of an Operational Reserve, a Debt Service Reserve, a Capital Expenditures Reserve, a General Fund Transfer Reserve, an Energy Services Charge Reserve, a Transmission Services Charge Reserve, and a Contingency Reserve.”

53 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2

13.04.040 Residential single-family service (R-1)

13.04.040 Customer Charger per meter per month $8.96000 $11.15000 $13.25000

13.04.040 Grid Access Charge per meter per month $4.50000 $6.50000 $8.50000

13.04.040 Distribution Charge per kWh on the first 350 kWh per month $0.01889 $0.03505 $0.04836

13.04.040 Distribution Charge per kWh on the 351 to 750 kWh per month $0.14673 $0.14018 $0.19345

13.04.040 Distribution Charge per kWh on use over 751 kWh per month $0.10706 $0.25233 $0.34822

13.04.040 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609

13.04.040 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07073 $0.15057 $0.12072

13.04.040 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06147 $0.13085 $0.10492

13.04.040 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.14750 $0.31399 $0.25175

13.04.040 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.04750 $0.10112 $0.08107

13.04.040 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.040 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.11150 $0.11150 $0.23736

13.04.040 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05100 $0.05100 $0.10857

13.04.040 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.045 Residential multi-family service (R-2)

13.04.045 Customer Charger per meter per month $8.96000 $11.15000 $13.25000

13.04.045 Grid Access Charge per meter per month $4.50000 $6.50000 $8.50000

13.04.045 Distribution Charge per kWh on the first 350 kWh per month $0.01889 $0.03505 $0.04836

13.04.045 Distribution Charge per kWh on the 351 to 750 kWh per month $0.14673 $0.14018 $0.19345

13.04.045 Distribution Charge per kWh on use over 751 kWh per month $0.10706 $0.25233 $0.34822

13.04.045 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609

13.04.045 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07073 $0.15057 $0.12072

13.04.045 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06147 $0.13085 $0.10492

13.04.045 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.14750 $0.31399 $0.25175

13.04.045 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.04750 $0.10112 $0.08107

13.04.045 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.045 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.11150 $0.11150 $0.23736

13.04.045 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05100 $0.05100 $0.10857

13.04.045 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.050 Small commerical and institutional serivce (S-1)

13.04.050 Customer Charger per meter per month $9.42000 $15.00000 $20.65000

13.04.050 Grid Access Charge per meter per month $17.00000 $17.00000 $17.00000

13.04.050 Distribution Charge per kWh per month $0.06423 $0.06862 $0.07300

13.04.050 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609

13.04.050 Energy Service Charge Flat Rate Option per kWh in the High Season $0.06901 $0.13988 $0.13107

13.04.050 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06030 $0.12223 $0.11453

13.04.050 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10463 $0.21208 $0.19872

13.04.050 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05706 $0.11566 $0.10837

13.04.050 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.050 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06431 $0.13036 $0.12214

13.04.050 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05611 $0.11373 $0.10657

13.04.050 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.050 Minimum Monthly Charge (Customer Charge + Grid Access Charge) $26.42000 $32.00000 $37.65000

13.04.060 Medium commerical and institutional service - secondary (M-1)

13.04.060 Customer Charger per meter per month $23.40000 N/A N/A

13.04.060 Grid Access Charge per meter per month $250.00000 N/A N/A

13.04.060 Distribution Charge per kW of billing demand per month $16.09000 N/A N/A

13.04.060 Transmission Charge per kWh per month $0.01609 N/A N/A

13.04.060 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07338 N/A N/A

13.04.060 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06213 N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10218 N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.06063 N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06578 N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05785 N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.060 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) $756.10000 N/A N/A

13.04.060 Medium commerical service - secondary (M-2)

13.04.060 Customer Charger per meter per month N/A $35.00000 $50.00000

13.04.060 Grid Access Charge per meter per month N/A $250.00000 $250.00000

13.04.060 Distribution charge per kW of billing demand per month N/A $18.00000 $20.90000 ATTACHMENT B: RATE SCHEDULE ALTERNATIVE 1
1 of 5
54 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT B: RATE SCHEDULE ALTERNATIVE 1

13.04.060 Transmission Charge per kWh per month N/A $0.01609 $0.01609

13.04.060 Energy Service Charge Flat Rate Option per kWh in the High Season N/A $0.12465 $0.11316

13.04.060 Energy Service Charge Flat Rate Option per kWh in the Low Season N/A $0.10554 $0.09581

13.04.060 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.17358 $0.15757

13.04.060 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.10299 $0.09349

13.04.060 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.11174 $0.10144

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.09827 $0.08921

13.04.060 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.060 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) N/A $825.00000 $927.00000

13.04.064 Medium commerical and institutional service - primary (M-2)

13.04.064 Customer Charger per meter per month $29.75000 N/A N/A

13.04.064 Grid Access Charge per meter per month $250.00000 N/A N/A

13.04.064 Distribution Charge per kW of billing demand per month $11.49000 N/A N/A

13.04.064 Transmission Charge per kWh per month $0.01590 N/A N/A

13.04.064 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07154 N/A N/A

13.04.064 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06121 N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10128 N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05970 N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06481 N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05713 N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.064 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) $624.45000 N/A N/A

13.04.064 Medium commercial service - primary (M-1)

13.04.064 Customer Charger per meter per month N/A $44.50000 $63.60000

13.04.064 Grid Access Charge per meter per month N/A $250.00000 $250.00000

13.04.064 Distribution Charge per kW of billing demand per month N/A $12.00000 $14.00000

13.04.064 Transmission Charge per kWh per month N/A $0.01590 $0.01590

13.04.064 Energy Service Charge Flat Rate Option per kWh in the High Season N/A $0.12153 $0.11032

13.04.064 Energy Service Charge Flat Rate Option per kWh in the Low Season N/A $0.10398 $0.09439

13.04.064 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.17205 $0.15618

13.04.064 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.10153 $0.09217

13.04.064 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.11009 $0.09994

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.09705 $0.08810

13.04.064 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.064 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) N/A $654.50000 $733.60000

13.04.067 Large commercial and institutional service—secondary (L-1)

13.04.067 Customer Charger per meter per month $47.91000 N/A N/A

13.04.067 Grid Access Charge per meter per month $1,500.00000 N/A N/A

13.04.067 Distribution Charge per kW of billing demand per month $18.76000 N/A N/A

13.04.067 Transmission Charge per kWh per month $0.01609 N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10394 N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05843 N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06579 N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05659 N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.067 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) $7,175.91000 N/A N/A

13.04.067 Large commercial and institutional service—secondary (L-2)

13.04.067 Customer Charger per meter per month N/A $75.00000 $100.00000

13.04.067 Grid Access Charge per meter per month N/A $1,500.00000 $1,500.00000

13.04.067 Distribution Charge per kW of billing demand per month N/A $20.40000 $22.80000

13.04.067 Transmission Charge per kWh per month N/A $0.01609 $0.01609

13.04.067 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.16979 $0.15868

13.04.067 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.09545 $0.08920

13.04.067 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.10747 $0.10044

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.09244 $0.08639

13.04.067 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.067 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) N/A $7,695.00000 $8,440.000002 of 5 55 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT B: RATE SCHEDULE ALTERNATIVE 1

13.04.069 Large commercial and institutional service—primary (L-1)

13.04.069 Customer Charger per meter per month N/A $84.40000 $112.50000

13.04.069 Grid Access Charge per meter per month N/A $1,500.00000 $1,500.00000

13.04.069 Distribution Charge per kW of billing demand per month N/A $18.00000 $20.00000

13.04.069 Transmission Charge per kWh per month N/A $0.01590 $0.01590

13.04.069 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.16094 $0.15040

13.04.069 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.09115 $0.08519

13.04.069 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.10809 $0.10102

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.09195 $0.08593

13.04.069 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.069 Minimum Monthly Charge (Customer Charge + Distribution Charge x 300kW + Grid Access Charge) N/A $6,984.40000 $7,612.50000

13.04.070 Large commercial and institutional service—primary (L-2)

13.04.070 Customer Charger per meter per month $53.90000 N/A N/A

13.04.070 Grid Access Charge per meter per month $1,500.00000 N/A N/A

13.04.070 Distribution Charge per kW of billing demand per month $11.89000 N/A N/A

13.04.070 Transmission Charge per kWh per month $0.01590 N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.09852 N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05580 N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06617 N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05629 N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.070 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) $5,120.90000 N/A N/A

13.04.070 Extra-Large commercial and institutional service—primary (L-3)

13.04.070 Customer Charger per meter per month N/A

13.04.070 Grid Access Charge per meter per month N/A

13.04.070 Distribution Charge per kW of billing demand per month N/A

13.04.070 Transmission Charge per kWh per month N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.070 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) N/A $0.00000 $0.00000

13.04.080 Standby Service (SBY)

13.04.080 Distribution Charge per kW of standby capacity $10.87000

13.04.080 Customer Charge N/A

13.04.080 Grid Access Charge per meter per month N/A

13.04.080 Minimum Monthly charge (if less than demand charge) $201.40000

13.04.080 Standby service application charge on-time fee for each application or customer account $5.00000

13.04.080 Reservation Charge N/A

13.04.085 Unmetered rates- Non-demand (CE-1)

13.04.085 Customer Charge per meter per month (single-phase service) $14.16000

13.04.085 Customer Charge per meter per month (three-phase service) $19.07000

13.04.085 Distribution Charge per kWh of billing demand per month $0.04475

13.04.085 Energy Service Charge Flat Rate per kWh in the High Season $0.06901

13.04.085 Energy Service Charge Flat Rate per kWh in the Low Season $0.06030

13.04.087 Unmetered rates- Demand (CE-2)

13.04.087 Customer Charge per meter per month $60.22000

13.04.087 Distribution Charge per kWh of billing demand per month $10.87000

13.04.087 Energy Service Charge Flat Rate per kWh in the High Season $0.07338

13.04.087 Energy Service Charge Flat Rate per kWh in the Low Season $0.06213

13.04.090 Street lighting and traffic signal service (SL) may have new lamp types

13.04.090 Incandescent 1,000 lumens per lamp per month $0.94000 $1.24798 $1.24798

13.04.090 Incandescent 1,500 lumens per lamp per month $1.11000 $1.47368 $1.47368

13.04.090 Incandescent 2,500 lumens per lamp per month $1.95000 $2.58889 $2.58889

13.04.090 Incandescent 4,000 lumens per lamp per month $3.14000 $4.16878 $4.16878

13.04.090 Incandescent 6,000 lumens per lamp per month $4.47000 $5.93454 $5.93454

13.04.090 Incandescent 10,000 lumens per lamp per month $6.79000 $9.01466 $9.01466

13.04.090 Incandescent 67 watts per lamp per month $0.86000 $1.14177 $1.141773 of 5 56 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT B: RATE SCHEDULE ALTERNATIVE 1

13.04.090 Incandescent 69 watts per lamp per month $0.88000 $1.16832 $1.16832

13.04.090 Incandescent 103 watts per lamp per month $1.30000 $1.72593 $1.72593

13.04.090 Incandescent 150 watts per lamp per month $1.89000 $2.50923 $2.50923

13.04.090 Incandescent 202 watts per lamp per month $2.54000 $3.37220 $3.37220

13.04.090 Incandescent 303 watts per lamp per month $3.80000 $5.04502 $5.04502

13.04.090 Mercury Vapor 3,500 lumens per lamp per month $1.61000 $2.13750 $2.13750

13.04.090 Mercury Vapor 7,000 lumens per lamp per month $2.64000 $3.50496 $3.50496

13.04.090 Mercury Vapor 11,000 lumens per lamp per month $3.66000 $4.85915 $4.85915

13.04.090 Mercury Vapor 20,000 lumens per lamp per month $5.80000 $7.70030 $7.70030

13.04.090 Mercury Vapor 35,000 lumens per lamp per month $9.81000 $13.02412 $13.02412

13.04.090 Mercury Vapor 54,000 lumens per lamp per month $13.87000 $18.41433 $18.41433

13.04.090 Mercury Vapor Fluorescent per lamp per month

13.04.090 Mercury Vapor 213 watts per lamp per month $2.68000 $3.55807 $3.55807

13.04.090 Mercury Vapor 248 watts per lamp per month $3.14000 $4.16878 $4.16878

13.04.090 High Pressure Sodium 35 watts per lamp per month $0.51000

13.04.090 High Pressure Sodium 50 watts per lamp per month $0.72000

13.04.090 High Pressure Sodium 70 watts per lamp per month $1.28000 $1.69938 $1.69938

13.04.090 High Pressure Sodium 100 watts per lamp per month $1.76000 $2.33664 $2.33664

13.04.090 High Pressure Sodium 150 watts per lamp per month $2.43000 $3.22616 $3.22616

13.04.090 High Pressure Sodium 200 watts per lamp per month $3.09000 $4.10240 $4.10240

13.04.090 High Pressure Sodium 250 watts per lamp per month $3.94000 $5.23089 $5.23089

13.04.090 High Pressure Sodium 310 watts per lamp per month $4.81000 $6.38593 $6.38593

13.04.090 High Pressure Sodium 400 watts per lamp per month $5.98000 $7.93927 $7.93927

13.04.090 High Pressure Sodium 4—60 watts unit bus stop per lamp per month $4.82000 $6.39921 $6.39921

13.04.090 High Pressure Sodium 2—40 watts unit bus stop per lamp per month $4.82000 $6.39921 $6.39921

13.04.090 Metal Halide per lamp per month $3.99000 $5.29727 $5.29727

13.04.090 Districution Charge for metered street lighting per kWh $0.03923 $0.05208 $0.05208

13.04.090 Distribution Charge metered traffic signals and signs per kWh $0.05807 $0.09465 $0.09465

13.04.090 Distribution Charge Unmetered traffic signals and signs $0.05807 $0.09465 $0.09465

13.04.090 Energy Charge per kWh $0.06500 $0.18361 $0.18361

13.04.150 Rate schedule change

13.04.150 Load change in less than 12 months per meter affected $3.00000 Not specified Not specified

13.04.176 Feed-in-tariff (FIT) N/A

13.04.177 Net energy metering (NEM)

13.04.177 B. Annual NEM
B. Annual NEM: energy services charge over the customer's billing period plus 2.5¢ per kWh for RECs
No new cust after 1/1/2026, rate for net
surplus electricity compensation shall
be equal to the applicable energy
services charge over the customer's
billing period plus 2.5¢ per kWh for
RECs
No new cust after 1/1/2026, rate for net
surplus electricity compensation shall be
equal to the applicable energy services
charge over the customer's billing period
plus 2.5¢ per kWh for RECs

13.04.177 C. Monthly/Bi-Monthly NEM
C. Monthly/Bi-Monthly NEM: energy services charge over the billing period plus 6.6¢ per kWh plus 2.5¢ per kWh for RECs
No new cust after 1/1/2026, credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus 2.5¢ per kWh for
RECs
No new cust after 1/1/2026, credit in an
amount equal to the net electricity delivered
to PWP multiplied by the applicable energy
services charge over the billing period plus

2.5¢ per kWh for RECs

13.04.177 D. Net Energy Metering (on or after January 1, 2026) D. sum of all rates set forth in the applicable rate schedule on the gross electric metered usage for all charges except the energy service charge. 1.receive a credit in an amount equal to the net electricity delivered to PWP multiplied by the applicable energy services charge.

On or after 1/1/2026 net surplus
electricity or net neutral electricity,
customer shall receive a credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus the premium
established for renewable energy
attributes credits in the Green Power
Program set forth in 13.04.179
On or after 1/1/2026 net surplus electricity or
net neutral electricity, customer shall receive
a credit in an amount equal to the net
electricity delivered to PWP multiplied by the
applicable energy services charge over the
billing period plus the premium established
for renewable energy attributes credits in the
Green Power Program set forth in 13.04.179
4 of 5
57 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT B: RATE SCHEDULE ALTERNATIVE 1

13.04.178 Self-generation service (SG)
B. Rates. Rates for this service shall be the same as for the schedule under which the customer would ordinarily take service, with the following exceptions: 1. For self-generation service customers in the residential and small commercial and industrial groups, the monthly customer charge and the distribution services charge shall respectively be the same as those of the medium commercial and industrial class—secondary. 2. In each month, billing demand will be the greater of the maximum fifteen minute kW of the absolute net power that the customer received from or injected into the PWP power system during the current month or preceding eleven months. 3. In each month, the billing determinant for the Transmission Services Charge shall be the sum, over the hours of the month, of the hourly net power that the customer received from the PWP power system, but in no event less than zero for the month.4.For energy charges and energy credits, billing determinants shall be quantified as follows:a.For customers on seasonal flat energy rates, the monthly billing determinant shall be the net power that the customer received from the PWP power system during the month.b.For customers on time-of- use (TOU) energy rates, the billing determinant for each TOU period shall be the net power that the customer received from the PWP power system during each period.5.For any period during which the customer's net power received from the PWP power system is negative (i.e., during which the customer injects net power into the PWP power system), the customer shall not pay an Energy Charge but shall instead receive an energy credit.a.The applicable energy credit periods shall be one month for customers on seasonal flat rates and TOU periods for customers on TOU rates.b.The energy credit for each period shall equal the product of:1.The customer's net injection into the PWP power system during the period and PWP's average power cost applicable to that period.

1. Time-of-use rates under which the
customer would ordinarily take service
except, (1) in each month, billing
demand will be the greater of the
maximum 15 minute kW of the absolute
net electricity delivered to customer
during the current month or preceding
11 months and (2) in each month, the
billing determinant for the transmission
services charge shall be the sum, over
the hours of the month, of the hourly net
power that the customer received from
the PWP power system, but in no event
less than zero for the month.

2. Customer shall receive a credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge.

1. Time-of-use rates under which the
customer would ordinarily take service
except, (1) in each month, billing demand will
be the greater of the maximum 15 minute kW
of the absolute net electricity delivered to
customer during the current month or
preceding 11 months and (2) in each month,
the billing determinant for the transmission
services charge shall be the sum, over the
hours of the month, of the hourly net power
that the customer received from the PWP
power system, but in no event less than zero
for the month.

2. Customer shall receive a credit in an
amount equal to the net electricity delivered
to PWP multiplied by the applicable energy
services charge.

13.04.179 Green power service (GP)

13.04.179 Green power premium per kWh $0.01800

13.04.179 Green power premium for 100 kWh block $1.80000

13.04.180 Theft of energy

13.04.180 Minimum charge per occurrence of energy theft $300.00000 5 of 5
58 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3

13.04.040 Residential single-family service (R-1)

13.04.040 Customer Charger per meter per month $8.96000 $11.15000 $12.75000 $13.25000

13.04.040 Grid Access Charge per meter per month $4.50000 $6.50000 $7.50000 $8.50000

13.04.040 Distribution Charge per kWh on the first 350 kWh per month $0.01889 $0.03505 $0.04170 $0.04836

13.04.040 Distribution Charge per kWh on the 351 to 750 kWh per month $0.14673 $0.14018 $0.16682 $0.19345

13.04.040 Distribution Charge per kWh on use over 751 kWh per month $0.10706 $0.25233 $0.30027 $0.34822

13.04.040 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609 $0.01609

13.04.040 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07073 $0.06525 $0.09056 $0.10002

13.04.040 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06147 $0.05671 $0.07870 $0.08693

13.04.040 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.14750 $0.13607 $0.18885 $0.20859

13.04.040 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.04750 $0.04382 $0.06081 $0.06717

13.04.040 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.040 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.11150 $0.11150 $0.10286 $0.14276

13.04.040 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05100 $0.05100 $0.04705 $0.06530

13.04.040 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.045 Residential multi-family service (R-2)

13.04.045 Customer Charger per meter per month $8.96000 $11.15000 $12.75000 $13.25000

13.04.045 Grid Access Charge per meter per month $4.50000 $6.50000 $7.50000 $8.50000

13.04.045 Distribution Charge per kWh on the first 350 kWh per month $0.01889 $0.03505 $0.04170 $0.04836

13.04.045 Distribution Charge per kWh on the 351 to 750 kWh per month $0.14673 $0.14018 $0.16682 $0.19345

13.04.045 Distribution Charge per kWh on use over 751 kWh per month $0.10706 $0.25233 $0.30027 $0.34822

13.04.045 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609 $0.01609

13.04.045 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07073 $0.06525 $0.09056 $0.10002

13.04.045 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06147 $0.05671 $0.07870 $0.08693

13.04.045 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.14750 $0.13607 $0.18885 $0.20859

13.04.045 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.04750 $0.04382 $0.06081 $0.06717

13.04.045 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.045 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.11150 $0.11150 $0.10286 $0.14276

13.04.045 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05100 $0.05100 $0.04705 $0.06530

13.04.045 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.050 Small commerical and institutional serivce (S-1)

13.04.050 Customer Charger per meter per month $9.42000 $15.00000 $18.50000 $20.65000

13.04.050 Grid Access Charge per meter per month $17.00000 $17.00000 $17.00000 $17.00000

13.04.050 Distribution Charge per kWh per month $0.06423 $0.06862 $0.07081 $0.07300

13.04.050 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609 $0.01609

13.04.050 Energy Service Charge Flat Rate Option per kWh in the High Season $0.06901 $0.09780 $0.13113 $0.14147

13.04.050 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06030 $0.08546 $0.11458 $0.12361

13.04.050 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10463 $0.14828 $0.19882 $0.21448

13.04.050 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05706 $0.08087 $0.10842 $0.11697

13.04.050 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.050 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06431 $0.09114 $0.12220 $0.13183

13.04.050 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05611 $0.07952 $0.10662 $0.11502

13.04.050 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.050 Minimum Monthly Charge (Customer Charge + Grid Access Charge) $26.42000 $32.00000 $35.50000 $37.65000

13.04.060 Medium commerical and institutional service - secondary (M-1)

13.04.060 Customer Charger per meter per month $23.40000 N/A N/A N/A

13.04.060 Grid Access Charge per meter per month $250.00000 N/A N/A N/A

13.04.060 Distribution Charge per kW of billing demand per month $16.09000 N/A N/A N/A

13.04.060 Transmission Charge per kWh per month $0.01609 N/A N/A N/A

13.04.060 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07338 N/A N/A N/A

13.04.060 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06213 N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10218 N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.06063 N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06578 N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05785 N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.060
Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) $756.10000 N/A N/A N/A

13.04.060 Medium commerical service - secondary (M-2)

13.04.060 Customer Charger per meter per month N/A $35.00000 $42.00000 $50.00000

13.04.060 Grid Access Charge per meter per month N/A $250.00000 $250.00000 $250.00000 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2
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59 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2

13.04.060 Distribution charge per kW of billing demand per month N/A $18.00000 $19.50000 $20.90000

13.04.060 Transmission Charge per kWh per month N/A $0.01609 $0.01609 $0.01609

13.04.060 Energy Service Charge Flat Rate Option per kWh in the High Season N/A $0.08760 $0.11557 $0.12265

13.04.060 Energy Service Charge Flat Rate Option per kWh in the Low Season N/A $0.07417 $0.09785 $0.10384

13.04.060 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.12198 $0.16093 $0.17078

13.04.060 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.07238 $0.09549 $0.10134

13.04.060 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.07853 $0.10360 $0.10994

13.04.060 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.06906 $0.09111 $0.09669

13.04.060 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.060 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) N/A $825.00000 $877.00000 $927.00000

13.04.064 Medium commerical and institutional service - primary (M-2)

13.04.064 Customer Charger per meter per month $29.75000 N/A N/A N/A

13.04.064 Grid Access Charge per meter per month $250.00000 N/A N/A N/A

13.04.064 Distribution Charge per kW of billing demand per month $11.49000 N/A N/A N/A

13.04.064 Transmission Charge per kWh per month $0.01590 N/A N/A N/A

13.04.064 Energy Service Charge Flat Rate Option per kWh in the High Season $0.07154 N/A N/A N/A

13.04.064 Energy Service Charge Flat Rate Option per kWh in the Low Season $0.06121 N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10128 N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05970 N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06481 N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05713 N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.064 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) $624.45000 N/A N/A N/A

13.04.064 Medium commercial service - primary (M-1)

13.04.064 Customer Charger per meter per month N/A $44.50000 $53.40000 $63.60000

13.04.064 Grid Access Charge per meter per month N/A $250.00000 $250.00000 $250.00000

13.04.064 Distribution Charge per kW of billing demand per month N/A $12.00000 $13.00000 $14.00000

13.04.064 Transmission Charge per kWh per month N/A $0.01590 $0.01590 $0.01590

13.04.064 Energy Service Charge Flat Rate Option per kWh in the High Season N/A $0.08540 $0.11268 $0.11957

13.04.064 Energy Service Charge Flat Rate Option per kWh in the Low Season N/A $0.07307 $0.09641 $0.10231

13.04.064 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.12091 $0.15952 $0.16928

13.04.064 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.07135 $0.09414 $0.09990

13.04.064 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.07737 $0.10208 $0.10832

13.04.064 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.06820 $0.08998 $0.09549

13.04.064 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.064 Minimum Monthly Charge (Distribution Charge x 30kW + Customer Charge + Grid Access Charge) N/A $654.50000 $693.40000 $733.60000

13.04.067 Large commercial and institutional service—secondary (L-1)

13.04.067 Customer Charger per meter per month $47.91000 N/A N/A N/A

13.04.067 Grid Access Charge per meter per month $1,500.00000 N/A N/A N/A

13.04.067 Distribution Charge per kW of billing demand per month $18.76000 N/A N/A N/A

13.04.067 Transmission Charge per kWh per month $0.01609 N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.10394 N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05843 N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06579 N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05659 N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.067 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) $7,175.91000 N/A N/A N/A 2 of 6
60 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2

13.04.067 Large commercial and institutional service—secondary (L-2)

13.04.067 Customer Charger per meter per month N/A $75.00000 $87.50000 $100.00000

13.04.067 Grid Access Charge per meter per month N/A $1,500.00000 $1,500.00000 $1,500.00000

13.04.067 Distribution Charge per kW of billing demand per month N/A $20.40000 $21.60000 $22.80000

13.04.067 Transmission Charge per kWh per month $0.01609 $0.01609 $0.01609

13.04.067 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.11876 $0.15959 $0.17136

13.04.067 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.06676 $0.08972 $0.09633

13.04.067 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.07517 $0.10102 $0.10846

13.04.067 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.06466 $0.08689 $0.09330

13.04.067 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.067 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) N/A $7,695.00000 $8,067.50000 $8,440.00000

13.04.069 Large commercial and institutional service—primary (L-1)

13.04.069 Customer Charger per meter per month N/A $84.40000 $98.50000 $112.60000

13.04.069 Grid Access Charge per meter per month N/A $1,500.00000 $1,500.00000 $1,500.00000

13.04.069 Distribution Charge per kW of billing demand per month N/A $18.00000 $19.00000 $20.00000

13.04.069 Transmission Charge per kWh per month $0.01590 $0.01590 $0.01590

13.04.069 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A $0.11257 $0.15127 $0.16242

13.04.069 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A $0.06376 $0.08568 $0.09199

13.04.069 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A $0.07561 $0.10160 $0.10909

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A $0.06432 $0.08643 $0.09280

13.04.069 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.069 Minimum Monthly Charge (Customer Charge + Distribution Charge x 300kW + Grid Access Charge) N/A $6,984.40000 $7,298.50000 $7,612.60000

13.04.069 Large commercial and institutional service—primary (L-2)

13.04.069 Customer Charger per meter per month $53.90000 N/A N/A N/A

13.04.069 Grid Access Charge per meter per month $1,500.00000 N/A N/A N/A

13.04.069 Distribution Charge per kW of billing demand per month $11.89000 N/A N/A N/A

13.04.069 Transmission Charge per kWh per month $0.01590 N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh High Season On-Peak $0.09852 N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh High Season Off-Peak $0.05580 N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season On-Peak $0.06617 N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak $0.05629 N/A N/A N/A

13.04.069 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A N/A

13.04.069 Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) $5,120.90000 N/A N/A N/A

13.04.070 Extra-Large commercial and institutional service—primary (L-3)

13.04.070 Customer Charger per meter per month N/A

13.04.070 Grid Access Charge per meter per month N/A

13.04.070 Distribution Charge per kW of billing demand per month N/A

13.04.070 Transmission Charge per kWh per month N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A N/A N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A

13.04.070 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A N/A N/A

13.04.070
Minimum Monthly Charge (Distribution Charge x 300kW + Customer Charge + Grid Access Charge) N/A $0.00000 $0.00000 calculation

13.04.074 Electric vehicle charging below 30 kW (EV-1)

13.04.074 Customer Charger per meter per month N/A

13.04.074 Grid Access Charge per meter per month N/A

13.04.074 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A

13.04.074 Electric vehicle charging at or above 30kW and less than 300 kW (EV-2)

13.04.074 Customer Charger per meter per month N/A

13.04.074 Grid Access Charge per meter per month N/A

13.04.074 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A 3 of 6
61 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2

13.04.074 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A

13.04.074 Electric vehicle charging at or above 300 kW (EV-3)

13.04.074 Customer Charger per meter per month N/A

13.04.074 Grid Access Charge per meter per month N/A

13.04.074 Energy Service Charge Time-of-Use per kWh High Season On-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh High Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH High Season Critical Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season On-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWh Low Season Off-Peak N/A

13.04.074 Energy Service Charge Time-of-Use per kWH Low Season Critical Peak N/A

13.04.074 City-owned retail charging stations

13.04.074 Electric Vehicle Charging Fee Peak Hours 3:00 pm to 8:00 pm N/A

13.04.074 Electric Vehicle Charging Fee Off-Peak Hours (all other times) N/A

13.04.074 Electric Vehicle Charger Connection Fee N/A

13.04.074 Electric Vehicle Charger Connection Overstay Fee N/A

13.04.080 Standby Service (SBY)

13.04.080 Distribution Charge per kW of standby capacity $10.87000

13.04.080 Customer Charge N/A

13.04.080 Grid Access Charge per meter per month N/A

13.04.080 Minimum Monthly charge (if less than demand charge) $201.40000

13.04.080 Standby service application charge on-time fee for each application or customer account $5.00000

13.04.080 Reservation Charge N/A

13.04.085 Unmetered rates- Non-demand (CE-1)

13.04.085 Customer Charge per meter per month (single-phase service) $14.16000

13.04.085 Customer Charge per meter per month (three-phase service) $19.07000

13.04.085 Distribution Charge per kWh of billing demand per month $0.04475

13.04.085 Energy Service Charge Flat Rate per kWh in the High Season $0.06901

13.04.085 Energy Service Charge Flat Rate per kWh in the Low Season $0.06030

13.04.087 Unmetered rates- Demand (CE-2)

13.04.087 Customer Charge per meter per month $60.22000

13.04.087 Distribution Charge per kWh of billing demand per month $10.87000

13.04.087 Energy Service Charge Flat Rate per kWh in the High Season $0.07338

13.04.087 Energy Service Charge Flat Rate per kWh in the Low Season $0.06213 4 of 6
62 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2

13.04.090 Street lighting and traffic signal service (SL) may have new lamp types

13.04.090 Incandescent 1,000 lumens per lamp per month $0.94000 $1.04163 $1.23481 $1.30703

13.04.090 Incandescent 1,500 lumens per lamp per month $1.11000 $1.23000 $1.45813 $1.54341

13.04.090 Incandescent 2,500 lumens per lamp per month $1.95000 $2.16082 $2.56158 $2.71140

13.04.090 Incandescent 4,000 lumens per lamp per month $3.14000 $3.47947 $4.12480 $4.36605

13.04.090 Incandescent 6,000 lumens per lamp per month $4.47000 $4.95326 $5.87193 $6.21537

13.04.090 Incandescent 10,000 lumens per lamp per month $6.79000 $7.52408 $8.91955 $9.44124

13.04.090 Incandescent 67 watts per lamp per month $0.86000 $0.95298 $1.12972 $1.19580

13.04.090 Incandescent 69 watts per lamp per month $0.88000 $0.97514 $1.15599 $1.22361

13.04.090 Incandescent 103 watts per lamp per month $1.30000 $1.44055 $1.70772 $1.80760

13.04.090 Incandescent 150 watts per lamp per month $1.89000 $2.09433 $2.48276 $2.62797

13.04.090 Incandescent 202 watts per lamp per month $2.54000 $2.81461 $3.33662 $3.53178

13.04.090 Incandescent 303 watts per lamp per month $3.80000 $4.21083 $4.99180 $5.28376

13.04.090 Mercury Vapor 3,500 lumens per lamp per month $1.61000 $1.78406 $2.11494 $2.23865

13.04.090 Mercury Vapor 7,000 lumens per lamp per month $2.64000 $2.92542 $3.46798 $3.67082

13.04.090 Mercury Vapor 11,000 lumens per lamp per month $3.66000 $4.05569 $4.80789 $5.08909

13.04.090 Mercury Vapor 20,000 lumens per lamp per month $5.80000 $6.42705 $7.61906 $8.06468

13.04.090 Mercury Vapor 35,000 lumens per lamp per month $9.81000 $10.87058 $12.88671 $13.64044

13.04.090 Mercury Vapor 54,000 lumens per lamp per month $13.87000 $15.36952 $18.22005 $19.28572

13.04.090 Mercury Vapor Fluorescent per lamp per month

13.04.090 Mercury Vapor 213 watts per lamp per month $2.68000 $2.96974 $3.52053 $3.72644

13.04.090 Mercury Vapor 248 watts per lamp per month $3.14000 $3.47947 $4.12480 $4.36605

13.04.090 High Pressure Sodium 35 watts per lamp per month $0.51000

13.04.090 High Pressure Sodium 50 watts per lamp per month $0.72000

13.04.090 High Pressure Sodium 70 watts per lamp per month $1.28000 $1.41838 $1.68145 $1.77979

13.04.090 High Pressure Sodium 100 watts per lamp per month $1.76000 $1.95028 $2.31199 $2.44721

13.04.090 High Pressure Sodium 150 watts per lamp per month $2.43000 $2.69271 $3.19212 $3.37882

13.04.090 High Pressure Sodium 200 watts per lamp per month $3.09000 $3.42407 $4.05912 $4.29653

13.04.090 High Pressure Sodium 250 watts per lamp per month $3.94000 $4.36596 $5.17570 $5.47842

13.04.090 High Pressure Sodium 310 watts per lamp per month $4.81000 $5.33002 $6.31856 $6.68813

13.04.090 High Pressure Sodium 400 watts per lamp per month $5.98000 $6.62651 $7.85551 $8.31497

13.04.090 High Pressure Sodium 4—60 watts unit bus stop per lamp per month $4.82000 $5.34110 $6.33170 $6.70203

13.04.090 High Pressure Sodium 2—40 watts unit bus stop per lamp per month $4.82000 $5.34110 $6.33170 $6.70203

13.04.090 Metal Halide per lamp per month $3.99000 $4.42137 $5.24138 $5.54795

13.04.090 Districution Charge for metered street lighting per kWh $0.03923 $0.04347 $0.05153 $0.05455

13.04.090 Distribution Charge metered traffic signals and signs per kWh $0.05807 $0.06912 $0.08307 $0.09301

13.04.090 Distribution Charge Unmetered traffic signals and signs $0.05807 $0.06912 $0.08307 $0.09301

13.04.090 Energy Charge per kWh $0.06500 $0.15325 $0.18168 $0.19230

13.04.150 Rate schedule change

13.04.150 Load change in less than 12 months per meter affected $3.00000 Not specified Not specified

13.04.176 Feed-in-tariff (FIT) N/A

13.04.177 Net energy metering (NEM)

13.04.177 B. Annual NEM B. Annual NEM: energy services charge over the customer's billing period plus 2.5¢ per kWh for RECs
No new cust after 1/1/2026, rate for net
surplus electricity compensation shall
be equal to the applicable energy
services charge over the customer's
billing period plus 2.5¢ per kWh for RECs
No new cust after 1/1/2026, rate for
net surplus electricity compensation
shall be equal to the applicable energy
services charge over the customer's
billing period plus 2.5¢ per kWh for
RECs

13.04.177 C. Monthly/Bi-Monthly NEM C. Monthly/Bi-Monthly NEM: energy services charge over the billing period plus 6.6¢ per kWh plus 2.5¢ per kWh for RECs
No new cust after 1/1/2026, credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus 2.5¢ per kWh for
RECs
No new cust after 1/1/2026, credit in
an amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus 2.5¢ per kWh for
RECs
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63 MUNICIPAL CODE SECTIONMUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 Phase 3 ATTACHMENT C: RATE SCHEDULE ALTERNATIVE 2

13.04.177 D. Net Energy Metering (on or after January 1, 2026) D. sum of all rates set forth in the applicable rate schedule on the gross electric metered usage for all charges except the energy service charge. 1.receive a credit in an amount equal to the net electricity delivered to PWP multiplied by the applicable energy services charge.

On or after 1/1/2026 net surplus
electricity or net neutral electricity,
customer shall receive a credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus the premium
established for renewable energy
attributes credits in the Green Power
Program set forth in 13.04.179
On or after 1/1/2026 net surplus
electricity or net neutral electricity,
customer shall receive a credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge over
the billing period plus the premium
established for renewable energy
attributes credits in the Green Power
Program set forth in 13.04.179

13.04.178 Self-generation service (SG)
B. Rates. Rates for this service shall be the same as for the schedule under which the customer would ordinarily take service, with the following exceptions: 1. For self- generation service customers in the residential and small commercial and industrial groups, the monthly customer charge and the distribution services charge shall respectively be the same as those of the medium commercial and industrial class—secondary. 2. In each month, billing demand will be the greater of the maximum fifteen minute kW of the absolute net power that the customer received from or injected into the PWP power system during the current month or preceding eleven months. 3. In each month, the billing determinant for the Transmission Services Charge shall be the sum, over the hours of the month, of the hourly net power that the customer received from the PWP power system, but in no event less than zero for the month.4.For energy charges and energy credits, billing determinants shall be quantified as follows:a.For customers on seasonal flat energy rates, the monthly billing determinant shall be the net power that the customer received from the PWP power system during the month.b.For customers on time-of-use (TOU) energy rates, the billing determinant for each TOU period shall be the net power that the customer received from the PWP power system during each period.5.For any period during which the customer's net power received from the PWP power system is negative (i.e., during which the customer injects net power into the PWP power system), the customer shall not pay an Energy Charge but shall instead receive an energy credit.a.The applicable energy credit periods shall be one month for customers on seasonal flat rates and TOU periods for customers on TOU rates.b.The energy credit for each period shall equal the product of:1.The customer's net injection into the PWP power system during the period and PWP's average power cost applicable to that period.

1. Time-of-use rates under which the
customer would ordinarily take service
except, (1) in each month, billing
demand will be the greater of the
maximum 15 minute kW of the absolute
net electricity delivered to customer
during the current month or preceding 11
months and (2) in each month, the billing
determinant for the transmission
services charge shall be the sum, over
the hours of the month, of the hourly net
power that the customer received from
the PWP power system, but in no event
less than zero for the month.

2. Customer shall receive a credit in an
amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge.

1. Time-of-use rates under which the
customer would ordinarily take service
except, (1) in each month, billing
demand will be the greater of the
maximum 15 minute kW of the
absolute net electricity delivered to
customer during the current month or
preceding 11 months and (2) in each
month, the billing determinant for the
transmission services charge shall be
the sum, over the hours of the month,
of the hourly net power that the
customer received from the PWP
power system, but in no event less
than zero for the month.

2. Customer shall receive a credit in
an amount equal to the net electricity
delivered to PWP multiplied by the
applicable energy services charge.

13.04.179 Green power service (GP)

13.04.179 Green power premium per kWh $0.01800 $0.01800

13.04.179 Green power premium for 100 kWh block $1.80000 $1.80000

13.04.180 Theft of energy

13.04.180 Minimum charge per occurrence of energy theft $300.00000 $300.00000 6 of 6
64 ITEM #2
65 PASADENA WATER AND POWER

MEMORANDUM
December 09, 2025
To: Munic
ipal Services Committee
From: D
avid M. Reyes
General Manager
Subje
ct: Utility Undergrounding Overview
Att
ached for the Municipal Services Committee is a presentation from Pasadena Water and Power (“PWP”) providing a summary of utility undergrounding projects. This is presented as an informational item.

The pres
entation details PWP’s existing robust underground systems, recent undergrounding accomplishments, upcoming underground utility district projects, high voltage undergrounding projects currently in progress in high fire threat districts, and possible long-term strategies and goals.

Attac
hment: Utility Undergrounding Overview Presentation
66 Pasadena Water & Power
Utility Undergrounding Overview
Current State and Future Outlook
Municipal Services Committee
December 9, 2025
Item #2
67 Pasadena Water & Power
Underground vs Overhead Breakdown
2 All UG
Conductors
(Citywide)
All UG Conductors
(High Threat Fire
District)

60.4% 65.4%
HV OH
HV UG
City Border
68 Pasadena Water & Power
Types of Undergrounding Projects
3 • Formal Underground Utility District (UUD)
> Undergrounding of all overhead wires (electric,
telecommunications, streetlights, etc.) – Poles
are removed
• Utility–Driven Projects
> Undergrounding of high and/or low voltage
electrical wires only – Poles remains
▪ Undergrounding in high fire threat areas
▪ Development and service level work with
requirements to underground
69 Pasadena Water & Power
4 • Recently Completed Projects
>Hill Avenue
>Alpine Street
• Current and Future Projects
>Raymond Avenue
>Mountain Street
UUD Projects
70 Pasadena Water & Power
Hill UUD – Completed
5 Hill Avenue (District 04-02)
Boundary: Villa Street to North
City Limits
Distance: 1.42 Miles
Total Cost: $19,600,000
Utility Poles: 60
Parcels: 207
Meters: 445
Districts: 2
71 Pasadena Water & Power
Alpine UUD – Completed
6 Alpine Street (District 08-01)
Boundary: Marengo Avenue to
El Molino Avenue
Distance: 0.548 Miles
Total Cost: $7,800,000
Utility Poles: 25
Parcels: 54
Meters: 202
Districts: 6 and 7
72 Pasadena Water & Power
Raymond UUD (Starting in 2026)
7 Raymond Avenue (District 06-01)
Boundary: Maple Street to North
City Limits
Distance: 2.02 Miles
Budget: $43,800,000
Utility Poles: 61
Parcels: 247
Meters: 268
Districts: 1, 3, and 5
73 Pasadena Water & Power
Mountain UUD (Starting in 2029)
8 Mountain Street (District 10-1)
Boundary: Lake Ave to Hill Ave
Distance: 0.623 Miles
Budget: $13,600,000
Utility Poles: 30
Parcels: 58
Meters: 81
Districts: 2 and 5
74 Pasadena Water & Power
High Voltage Undergrounding (HVUG)
in High Fire Threat Districts
• Objective is to mitigate the ignition risk of high
voltage lines
• Specific projects are approved within existing Fire
Threat Mitigation Capital Improvement Programs
• Substructures are installed in the public right-of-way for high and low voltage underground electrical
equipment
9 75
Pasadena Water & Power
High Voltage Undergrounding (HVUG)
in High Fire Threat Districts
• High voltage underground equipment are installed to
allow for removal of overhead high voltage lines
• Existing low voltage wires, services, and poles
remain but are powered by the new underground
system
• Quicker execution and lower cost to allow for greater risk reduction sooner, without compromising future
full undergrounding
10 76
Pasadena Water & Power
High Fire Threat Districts
11 77
Pasadena Water & Power
Tier 3 – Canyon Close & Fox Ridge HVUG
12 Distance: 0.32 Miles
Total Cost: $2,500,000
Utility Poles: 15
Parcels: 57
Meters: 57
Districts: 4
Est. Completion: Early 2026
78 Pasadena Water & Power
Tier 3 – Florecita & Crestford HVUG
13 Distance: 0.42 Miles
Total Cost: $1,800,000
Utility Poles: 15
Parcels: 57
Meters: 57
Districts: 1
Est. Completion: End of 2026
79 Pasadena Water & Power
Tier 2 – HVUG Feasibility Map
14 Distance: 5.1 to 6.5 Miles
Estimated Cost: $32M to $42M
Estimated Duration: 12 to 16 years
Districts: 1, 4, and 6
80 Pasadena Water & Power
Possible Focused Path Forward
• Complete the Raymond and Mountain UUDs
• Concurrently start feasible Tier 2 HVUG projects in
FY 2027
• Focus on finishing feasible Tier 2 HVUG projects
prior to resuming formal UUD projects
15 81
Pasadena Water & Power
Questions & Discussion
Questions?
16 82