AGENDA
MUNICIPAL SERVICES COMMITTEE
REGULAR MEETING NOTICE
JANUARY 13, 2026
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.
In 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) 744-4124 at least 24 hours in advance.
Habrá servicio de interpretación disponible para éstas juntas llamando al (626) 744-4124 por lo menos con 24 horas de anticipación.
Items 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 JANUARY 13, 2026, AT 4:00 P.M. WILL BE ACCEPTED IN- PERSON AND BY VIDEOCONFERENCE/TELECONFERENCE.
Link to City Meeting Policy:
cityofpasadena.net/CityCouncilMeetingPolicy
TO 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-person Meeting Participation: Complete an online speaker card at the following website: www.cityofpasadena.net/commissions/public-comment/ 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 to the meeting using a computer, other electronic device, or by telephone. Please review the agenda to identify the published start time for the meeting and connect to the meeting just prior to, or at the start of the meeting.
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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: If 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:
Correspondence 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.
LIVESTREAM WITH CAPTIONING IS AVAILABLE AT WWW.PASADENAMEDIA.ORG, AND ALSO AT WWW.CITYOFPASADENA.NET/COMMISSIONS/AGENDAS,
IF YOU NEED A REASONABLE MODIFICATION OR ACCOMMODATION PURSUANT TO THE
AMERICANS WITH DISABILITIES ACT
BECAUSE YOU ARE UNABLE TO PARTICIPATE ELECTRONICALLY AS SET FORTH ABOVE, CONTACT THE CITY CLERK’S OFFICE
AS SOON AS POSSIBLE AT (626) 744-4124 OR [email protected].
CITY OF PASADENA
REGULAR MEETING OF
THE MUNICIPAL SERVICES COMMITTEE
JANUARY 13, 2026
PUBLIC MEETING: 4:00 PM
PASADENA CITY HALL, COUNCIL CHAMBER
100 NORTH GARFIELD AVENUE, ROOM S249
Teleconference Location:
Fairmont Orchid
1 N Kaniku Dr, Waimea, HI 96743
Room B1110
N
OTICE IS HEREBY GIVEN that the regular meeting of the Municipal Services Committee will be held on Tuesday, January 13, 2026, 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 January 8, 2026, 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.
REGULAR MEETING AGENDA
MUNICIPAL SERVICES COMMITTEE
JANUARY 13, 2026
Public Meeting: 4:00 P.M.
Council Chamber, Pasadena
City Hall 100 North Garfield Avenue, Room S249
T
eleconference Location:
Fairmont Orchid
1 N Kaniku Dr, Waimea, HI 96743
Room B1110
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
November 5, 2025 (Special Meeting)
November 11, 2025 (Cancelled Meeting)
November 25, 2025 (Cancelled Meeting)
December 9, 2025 (Regular Meeting)
December 18, 2025 (Cancelled Meeting)
December 23, 2025 (Cancelled Meeting)
1. S
ET 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. RAYMOND GROUNDWATER BASIN UPDATE
PUBLIC MEETING - 4:00 P.M.
ROLL CALL
PUBLIC COMMENT
ADJOURN
NEW BUSINESS/ACTION ITEMS
1 01 11/05/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
CITY HALL COUNCIL CHAMBER – S249
NOVEMBER 5, 2025
SPECIAL MEETING
OPENING The Chair called the special meeting of the Municipal Services Committee to order at 4:04 p.m.
ROLL CALL:
S
taff:
Councilmember Justin Jones, Chair
Councilmember Tyron Hampton (Arrived at 4:26 p.m.)
Councilmember Rick Cole
Councilmember Jason Lyon
David Reyes, General Manager of Water and Power
Kelly Nguyen, Assistant General Manager of Water and Power Evan Johnson, Customer Program Manager
Lisa Hosey, Assistant City Attorney
Betty Gao, Recording Secretary
NEW BUSINESS RECOMMENDATION TO APPROVE THE OPTIMIZED STRATEGIC
PLAN ESTABLISHING AN ACTION PLAN TO ACHIEVE THE GOALS
SET FORTH BY CITY COUNCIL-ADOPTED RESOLUTION 9977
C
ouncilmember Hampton
arrived at 4:26 p.m.
David Reyes, General Manager of Water and Power , provided introductory comments, and Kelly Nguyen, Assistant General Manager of Water and Power , summarized the agenda report as part of the PowerPoint presentation on the item, including providing information policy background, accomplishments, collaborative process, public engagement, Optimized Strategic Plan (OSP) highlights, case studies, planning targets, implementation roadmap, performance reporting; with both responding to questions.
Chair Jones acknowledged and thanked Pasadena Water and Power (PWP) and Technical Advisory Panel (TAP) staff for their extensive work in drafting the OSP.
General Manager Reyes echoed Chair Jones comments, recognizing TAP staff for their work in drafting the OSP . In response to correspondence received from the community , General Manager Reyes and Assistant General Manager Nguyen spoke on Pasadena’s partial ownership with Magnolia Power Projec t, incentives and permitting process, the importance of rooftop solar, the need for upcoming Request for Proposals (RFPs), ongoing collaboration across City departments and partner entities, the limited use of renewable natural gas, Net Energy Metering (NEM), and continuous monitoring of hydrogen. Mr. Reyes stated that staff will continue to monitor the OSP and provide an update to Committee early next year.
In response to Councilmember Cole’s concerns, General Manager Reyes clarified that the City currently has 30 MW and needs an additional 50 MW to reach the 80 MW goal. Councilmember Cole noted that meeting th e goal will require exceeding the minimum ranging shown in Table 4 (“Action plan for accelerating local solar and storage 2 02 11/05/2025
development”) in attachment A of the agenda report and emphasized the need for clearer understandable year-to year tracking of the OSP goals.
Councilmember Hampton advocated for staff to expand the incentives to allow residential solar systems to increase from 150% to 200% capacity, as well as providing incentives to support unlimited battery storage.
Chair Jones echoed Councilmember Hampton’s remarks advocating for financial incentives for residents; and asked staff to provide additional information on the distribution of local solar capacity across municipal rooftops and parking sites.
Betty Gao, Recording Secretary, reported that nineteen letters were 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 expressed concerns with the OSP timeline and language, spoke in favor of incentives for solar and battery projects, solar and battery installations, and/or provided other related comments on the matter:
Simon Anuszczyk, Pasadena resident
Genette Foster, Pasadena resident
Cynthia Cannady, representing Pasadena 100
Teresa Wong, San Gabriel resident
Audrey Ma, representing Pasadena 100
Wes Reutimann, Pasadena resident
Sandy Krasner, representing Pasadena 100
Felix Breden, representing Pasadena 100
Cecilia Abramson, representing Pasadena 100
Lauren Cory, representing Pasadena 100
Suzanne York, Pasadena resident
Sam Berndt, Pasadena resident
Jonah Kanner, Pasadena resident
Rex Mayreis, representing Citizens’ Climate Lobby
Rachel Kenney, Altadena resident
Joe Feinblatt, Pasadena resident
Alejandro Rivas, Pasadena resident
Councilmember Lyon thanked staff for their extensive work on the OSP; and made the following comments:
• He spoke in support of staff continuing to track the annual matching portfolio, noting it is the standard use statewide; • Echoed Councilmember Cole’s concerns related to the listed minimum ranges not meeting targeted goals;
• Stated that he believes the minimum solar ranges in the OSP should align and meet the overall targeted goal;
• Advocated for staff to include proposed capital investments programs;
• Spoke in support of staff strengthening the language in the OSP to encourag e solar programs to reflect a more proactive a nd robust approach to implementations and incentives;
3 03 11/05/2025
• Advocated for a dedicated professional staff or a point of contact to assist with the City’s solar programs and goals; and • Asked staff to agendize at a future Committee meeting the Magnolia Power Project ; and policy on com pensation and incentives for local solar generation.
Councilmember Hampton encouraged staff to engage and collaborate with the Pasadena Unified School District (PUSD) on solar planning and related initiatives. He advocated for an expedited permit process for solar installation; spoke on the importance of providing meter materials in a timely manner; and thanked staff for their hard work on the item.
Councilmember Cole thanked staff for all their hard work on the item and acknowledged Councilmember Lyon and Chair Jones for their efforts in advancing the drafting of the OSP. He echoed Councilmember Lyon’s comments regarding the need for dedicated staf f for the solar program and noted that Pasadena Water and Power (PWP) will require departmental structural adjustments to support the plan. He also requested further discussion on Net Energy Metering (NEM) and an evaluation of public benefit dollars to ensure maximum community benefit.
Chair Jones asked staff to report back to the Committee with an update of the Request for Proposal (RFP) process, solar barriers, NEM, and the Magnolia Power Project.
Councilmember Lyon echoed Councilmember Hampton’s comments on the need for incentives and proactive initiatives to support the OSP goals.
Following discussion, the Committee asked staff to amend the staff recommendation and provided direction to staff as follows:
• A mend the draft OSP to reflect hourly matching portfolio supporting Resolution 9977;
• Return to the Committee with information on Pasadena Water and Power’s optimal method to reorganize, which includes the staffing and structure to support the OSP implementation; • Increase additional solar requirement from 50 MW to 70 MW with at least 50 MW from Pasadena Water and Power customers; • Amend the draft OSP to include incentive timelines, realism and measurable goals in the draft language;
• Include realistic expectations for emerging technologies such as hydrogen;
• Increase solar capacity limits from 150% to 200%;
• Evaluate the City’s public benefits dollars to ensure the City is meeting the target of maximum conservation and renewable energy;
• Incorporate municipal solar considerations into future Capital Improvement Plan (CIP); and
• Evaluate municipal sites in the RFP process to determine where solar panels can be installed and provide an update to the Committee in January 2026
4 04 11/05/2025
Following further discussion, it was moved by Councilmember Cole, seconded by Councilmember Lyon, to approve staff’s
recommendations, amended and including direction to staff as detailed above, and forward the item to the City Council for consideration and further discussion. (Motion unanimously approved) (Absent: None)
INFORMATIONAL ONLY 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 COMMISSION
Following a brief discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.
EV CHARGING UPDATE
David Reyes , General Manager of Water and Power, provided introductory comments, and Evan Johnson, Customer Program Manager, summarized the staff memo as part of the PowerPoint presentation on the item, including providing information on climate commitment, importance of EVs, electric transportation goals, residential and commercial rebates, charging stations, operational challenges, mitigation measures, current and future projects, historical usage data; with both responding to questions.
Councilmember Hampton advocated for expanding the number of level- 3 (fast-charging) EV chargers to meet growing demand and improve reliability for EV users.
Councilmember Cole thanked staff for their knowledgeable and dedicated work, and contributions to the EV charging program.
Following discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.
Councilmember Cole requested that the Planning Commission’s work plan items related to Environmental Justice Element of the General Plan to be agendized for discussion at a future Committee meeting.
NEW BUSINESS
(CONTINUED)
CONSIDERATION OF CHANGES TO DATE AND TIME OF
REGULAR MSC MEETING
David Reyes, General Manager of Water and Power, provided introductory comments on the item and responded to questions.
Chair Jones supported the Committee to continuing meeting on Tuesday with a new proposed start time at 5:00 p.m.
5 05 11/05/2025
Councilmember Hampton expressed concerns regarding relocating the Design Commission’s meeting , noting he was not comfortable supporting the change until an alternative space is properly identified for the Commission.
Following discussion, it was moved by Councilmember Lyon, seconded by Councilmember Cole, to amend the start time of regular Municipal Services Committee meeting from 4:00 p.m. to 5:00 p.m. contingent on the Design Commission’s new meeting location:
AYES: Councilmembers Cole, Lyon, Chair Jones
NOES: None
ABSENT: None
ABSTAIN: Councilmember Hampton
ADJOURNMENT On the order of the Chair, the meeting of the Municipal Services Committee was adjourned at 6:32 p.m.
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
ATTEST:
____________________
Betty Gao
Recording Secretary
6 01 11/11/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
COUNCIL CHAMBER – ROOM S249
NOVEMBER 11, 2025
MEETING
The regular meeting of the Municipal Services Committee, scheduled for Tuesday, November 11, 2025, at 4:00 p.m., was cancelled due to the Veteran’s Day holiday as ordered on November 12, 2025, and was posted.
ATTEST:
____________________
Betty Gao
Recording Secretary
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
7 01 11/25/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
COUNCIL CHAMBER – ROOM S249
NOVEMBER 25, 2025
MEETING
The regular meeting of the Municipal Services Committee, scheduled for Tuesday, November 25, 2025, at 4:00 p.m., was cancelled due to the Thanksgiving holiday, as ordered on November 20, 2025, and was posted.
ATTEST:
____________________
Betty Gao
Recording Secretary
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
8 01 12/09/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
CITY HALL COUNCIL CHAMBER – S249
DECEMBER 9, 2025 MEETING
OPENING The Chair called the meeting of the Municipal Services Committee to order at 4:10 p.m.
ROLL CALL:
Staff:
Councilmember Justin Jones, Chair
Councilmember Tyron Hampton (Arrived at 5:03 p.m.)
Councilmember Rick Cole
Councilmember Jason Lyon
David Reyes, General Manager of Water and Power
Lynne Chaimowitz, Assistant General Manager of Water and Power Varoojan Avedian, Assistant General Manager of Water and Power Lisa Hosey, 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 Lyon, seconded by Coun cilmember Cole, to approve the minutes of October 14, 2025, and October 28, 2025, as submitted. (Motion unanimously approved ) (Absent:
Councilmember Hampton)
NEW BUSINESS ELECTRIC RATES RECOMMENDATION
Chair Jones reported that the staff presentation would focus on electric rates, and topics related to Net Energy Metering (NEM), updated redline ordinance, data analysis for cost -of-service, solar program incentives and Feed-in-tariff (FIT) program will be agendized at a future Committee meeting for consideration and discussion.
David Reyes, General Manager of Water and Power, provided introductory comments, 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 cost drivers, cost of service, affordability and support programs, rate comparison, customer feedback, and proposed changes, with both responding to questions.
Councilmember Cole commended staff for the comprehensive report and emphasized the need for greater transparency in the cost -of- service assumptions and allocations. He asked staff to provide commercial competitive cost comparisons to better evaluate rate impacts.
Councilmember Lyon thanked staff for the report and echoed Councilmember Cole’s remarks regarding the need for additional data analysis to better understand the cost -of-service and rate allocation assumptions.
9 02 12/09/2025
Councilmember Hampton
arrived at 5:03 p.m.
Chair Jones asked staff to provide alternative financial options to help mitigate the impact of the proposed rate increases on residents.
Betty Gao, Recording Secretary, reported that two 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 raised concerns with rate increases, advocated for solar education, and/or provided related comments on the matter:
Genette Foster, Pasadena resident
Cynthia Cannady, representing Pasadena 100
Lisa Zeigel, representing Pasadena 100
Wes Reutimann, Pasadena resident
Sam Berndt, Pasadena resident
Joe Feinblatt, Pasadena resident
Denise M., residence not stated
Tom King, Pasadena resident
Following discussion, t he Committee thanked Pasadena Water and Power staff and Assistant General Manager Jen Guess Mayo, for their diligent efforts on the item.
Following further discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.
INFORMATIONAL ONLY UTILITY UNDERGROUNDING OVERVIEW
David Reyes, General Manager of Water and Power, provided introductory comments, and Varoojan Avedian, 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 Underground Utility District (UUD) and utility-driven projects, and high fire threat districts, with both responding to questions.
Jim Spencer, Pasadena resident, voiced concerns regarding neighborhood safety and prioritization of undergrounding projects.
Councilmember Cole asked staff to reevaluat e the utility undergrounding program and associated fees and provide an update to the Committee at a future meeting.
The Committee expressed concerns with residents contributing to undergrounding fees without receiving a direct benefit.
Following discussion, the Committee asked staff to provide additional data on the UUD’s program rate structure, revenue data across the City, funds allocation, feasibility undergrounding map, neighboring cities’ undergrounding fees, and provide an update to the Committee for further discussion.
Following further discussion, on the order of the Chair, and by consensus of the Committee, the information was received and filed.
10 03 12/09/2025
Chair Jones stated that data center s’ environmental impacts will be considered and discussed at a future Committee meeting.
On the order of the Chair, the meeting of the Municipal Services Committee was adjourned at 6:03 p.m.
ADJOURNMENT
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
ATTEST:
____________________
Betty Gao
Recording Secretary
11 01 12/18/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY YARDS
233 WEST MOUNTAIN AVENUE
TRAINING ROOM
DECEMBER 18, 2025
SPECIAL MEETING
The special meeting of the Municipal Services Committee, scheduled for Thursday, December 18, 2025, at 5:00 p.m., was cancelled due to a lack of quorum as ordered on December 18, 2025, and was posted.
ATTEST:
____________________
Betty Gao
Recording Secretary
__________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
12 01 12/23/2025
CITY OF PASADENA
MUNICIPAL SERVICES COMMITTEE MINUTES
PASADENA CITY HALL
100 NORTH GARFIELD AVENUE
COUNCIL CHAMBER – ROOM S249
DECEMBER 23, 2025
MEETING
The regular meeting of the Municipal Services Committee, scheduled for Tuesday, December 23, 2025 , at 4:00 p.m., was cancelled as ordered on December 22, 2025, and was posted.
ATTEST:
____________________
Betty Gao
Recording Secretary
______________________________
Councilmember Justin Jones, Chair
Municipal Services Committee
13 ITEM #1
14 15
16 17
18 19
20 21
22 23
24 25
26 27
28 29
30 31
32 33
34 35
Janu
ary 12, 2026
TO: H
onorable Mayor and City Council
THRO
UGH: Municipal Services Committee (December 18, 2025)
FR
OM: Water and Power Department
SUBJ
ECT: 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
RECOMMENDATION:
It
is recommended that the City Council:
1) Fi
nd that the proposed action is not a project subject to the California Environmental Quality Act (CEQA) pursuant to Section 21065 of CEQA and Sections 15060(c)(2), 15060(c)(3), and 15378 of the State CEQA Guidelines and, as such, no environmental document pursuant to CEQA is required for the project; 2) Set a date of February 9, 2026, to conduct a public hearing for the recommended electric rate adjustments based on the findings of the recent electric rate study, with changes to take effect on March 1, 2026, or as soon thereafter as practicable; 3) Direct staff to prepare the Utility Rate Resolution using a two-year, three-phase rate adjustment (effective March 1, 2026, October 1, 2026, and March 1, 2027); and 4) Direct the City Attorney’s Office to prepare an ordinance within 60 days amending the Light and Power Rate Ordinance, Title 13, Chapter 13.04 – Power Rates and Regulations, to reflect the proposed electric rate adjustments, eliminate outdated or obsolete provisions, and align the ordinance with current industry best practices.
EXECUTIVE SUMMARY:
Pas
adena Water and Power (“PWP”) has completed a comprehensive Electric Rate Study to ensure that electric rates remain equitable, cost-based, and aligned with the City’s long-term goals of fiscal responsibility, infrastructure modernization, and achieving 100% carbon-free electricity by 2030. Conducted in partnership with NewGen Attachment A: December 9, 2025 and December 18, 2025 MSC Agenda Report and attachments. 36 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
S
trategies and Solutions, LLC (“NewGen”), the study includes a full cost-of-service (“COS”) analysis, financial modeling, and extensive public engagement. The study confirms that current electric rates are insufficient to meet projected revenue needs, with a shortfall of approximately $67.9 million over 2 years. To address this, PWP developed three rate adjustment alternatives. The recommended approach proposes a phased implementation over three steps allowing for gradual revenue recovery while maintaining reserve levels above policy minimums. This strategy balances financial sustainability with customer affordability and rate stability.
I
n addition to the rate adjustments, PWP recommends a full restatement of the Light and Power Rate Ordinance (Chapter 13.04) except for items related to Net Energy Metering and any new provisions for local solar that will have further discussion. This restatement will modernize the ordinance by eliminating outdated provisions, aligning terminology with current industry standards, and streamlining governance by moving all rate figures to the Electric Utility Rate Resolution. The updated ordinance also anticipates future needs, including time-of-use pricing, advanced metering infrastructure, and expanded support for distributed energy resources such as electric vehicles.
P
WP’s proposed rates remain among the most affordable in the region. The utility continues to prioritize equity by offsetting fixed charges for income-qualified customers and energy efficiency programs. Public engagement has been central to the process, with outreach efforts including webinars, open houses, and a dedicated website.
Feedback from residential and commercial customers has informed the rate design and highlighted interest in clean energy options, electric vehicle incentives, and bill transparency tools. PWP recommends that the City Council set a public hearing for February 9, 2026, to present the proposed rate adjustments and ordinance restatement, and to gather community input. If approved, the new rates would take effect beginning March 1, 2026, or as soon thereafter as practicable.
BACKG
ROUND:
O
n December 9, 2025, the Municipal Services Committee previously received a briefing on the state of the electric utility industry, regional rate trends, affordability considerations, public engagement efforts, and the policy and financial drivers behind the need for electric rate adjustments. That discussion, in Attachment A, addressed broader industry conditions, equity and affordability measures, public outreach, financial planning assumptions, and the multi-year rate strategy direction provided by the Committee.
T
his agenda item builds on that foundation and narrows the focus to two specific elements: the results of the Electric Cost-of-Service analysis and the introduction of new alternatives for consideration. The cost-of-service analysis provides the technical basis for aligning rates with the actual cost to deliver electric service in compliance with Proposition 26, while the alternatives offer additional context for evaluating rate design and implementation options. Together, these materials support informed decision- making without repeating prior background already reviewed by the Committee. 37 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
State of the Industry for the Cost-of-Service
Residential customers cost more to serve today than they did several decades ago for reasons that go beyond changes in how much electricity people use. Several independent analyses show structural and cost drivers that have increased the cost to serve residential customers:
• Infrastructure and distribution investments have grown significantly. Utilities across the state have raised spending on poles, wires, transformers, and other distribution system components to improve safety, reliability, and resilience.
These costs have been recovered through customer rates and are a principal driver of higher retail prices. According to the California Public Utilities Commission, distribution capital expenditures have grown sharply in recent years, and distribution spending is now the largest category of utility capital outlays
1. • Wildfire mitigation and grid hardening efforts have added new costs. Efforts to reduce wildfire risk—such as vegetation management, equipment upgrades, and other safety investments—have contributed materially to rising utility costs. One analysis of California investor-owned utilities found that wildfire mitigation spending accounted for a large share of above-inflation rate increases in recent years
2. • Residential rates have risen faster than inflation. California’s average residential electricity rates have grown significantly faster than inflation and now sit well above the national average. A Legislative Analyst’s Office report shows that residential electricity rates in the state increased by nearly 47% from 2019 to 2023, outpacing general price growth and contributing to higher costs for customers
3. • Fixed infrastructure costs are spread over lower per-customer usage.
Independent research has noted that California’s relatively flat per-capita electricity use means utilities must recover high fixed infrastructure costs (such as transmission and distribution) over less growth in energy sales. In other
1 Lawrence Berkeley National Laboratory, Retail Electricity Price and Cost Trends: 2024 Update, U.S. Department of Energy. The report identifies sustained growth in electric distribution system capital investments and concludes that increased spending on poles, wires, transformers, and grid modernization is a primary driver of rising retail electricity rates.
2 California Public Utilities Commission, Utility Wildfire Mitigation Cost Recovery and Grid Safety Reports. CPUC analyses confirm that wildfire mitigation and system hardening requirements have materially increased electric utility revenue requirements statewide. 3 California Legislative Analyst’s Office, Residential Electricity Rates in California, January 2025. The report concludes that residential electricity rates in California have increased substantially faster than inflation over the past several years and are among the highest in the nation, driven largely by capital investment, safety, and regulatory compliance costs.
38 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
words, the same network of poles and wires must be paid for even if consumption per household doesn’t grow4.
Taken together, these external analyses help explain why the cost to serve residential customers has increased so dramatically over time. The rise reflects long-term investments in grid modernization, safety improvements, and changing operational requirements, not simply changes in household energy usage.
ANALYSIS
The revenue requirement, cost-of-service analysis, and rate design are interdependent components of a single rate-setting framework and cannot be evaluated in isolation.
The revenue requirement establishes the total amount of funding needed to operate, maintain, and invest in the electric system. The cost-of-service analysis then allocates that revenue requirement to customer classes based on how customers use the system and drive costs. Rate design translates those class-level cost responsibilities into specific rate structures and prices that appear on customer bills.
As illustrated in Figure 1, each element relies on the others. Changes to the revenue requirement affect cost allocations, and changes in cost allocations directly influence rate design outcomes. As a result, no single component can stand alone without losing context or accuracy.
Figure 1: Cost of service Process: Aligning Cost and Pricing for Customer Types
4 Public Policy Institute of California, A Closer Look at California’s Surging Electricity Rates. The analysis explains that relatively flat residential electricity consumption, combined with rising fixed infrastructure and reliability costs, increases the cost burden per residential customer.
39 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
The detailed financial forecast that supports the revenue requirement has already been reviewed and discussed with the MSC. That work established the overall system funding needs and long-term financial assumptions. Accordingly, this agenda item does not revisit the full financial forecast and analysis presented in Attachment A and in the report on the Financial Forecast and Revenue Requirements. Instead, it focuses on the cost-of-service results and associated rate design considerations, which explain how those previously established revenue needs are distributed across customer classes and translated into rates.
PWP Cost-of-Service Study Findings: Aligning Costs with Customer Classifications
PWP with NewGen’s expertise used PWP accounting and demand data presented in the technical findings in the COS study, Attachment B. The technical findings of the cost-of-service study shows several customer classes are under-recovering costs, while others are above cost, leading to cross-subsidies. The study relied on customer data, PWP financials, system load profiles, and accepted industry methods.
PWP set out to evaluate the full cost of producing, transmitting, and delivering electricity. The study broke down the revenue requirement into production, transmission, distribution, and customer functions and then allocated these costs to each customer class based on how they use the system.
Key findings include:
• Production costs represent the largest share at 49%; distribution accounts for 41%.
• 77% of system costs are fixed.
• It costs about $125 per month to connect a residential customer to the system, regardless of usage.
• Current rates under-recover revenues for residential, small and large commercial, and traffic signal customers.
• Street lighting and medium commercial classes are above cost at present.
The COS analysis identifies the specific costs to serve each customer class using demand, energy, and customer allocation factors. These methods reflect customer contributions to peak load, energy use, and service requirements. PWP’s system has pronounced summer peaks, which drive investment decisions. The study uses four- coincident peak and non-coincident peak allocation factors that fit PWP’s load profile and operating conditions.
The COS results show that current rates do not match the actual cost to serve most customers. Residential customers face the largest gap, requiring an estimated one-time increase of about 39% to reach full cost recovery, compared to 7% for small commercial and 6% for large commercial. Medium commercial class is above cost and require adjustments downward to align with the COS Residential customers that fell out of 40 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
alignment with their actual cost to serve for a few reasons that show up directly in the study data.
First, residential customers place the largest share of demand on the system. They make up about 38% of the load during the four highest peak months, which is the period that drives most of PWP’s infrastructure costs. The system must be built and maintained to meet that peak, even though it only occurs a few hours per year. Residential demand during those hours pushes a large share of fixed production and distribution costs to this class.
Second, residential customers create the highest number of customer-related costs.
About 59,000 of PWP’s 68,000 electric accounts are residential. Activities like billing, metering, and customer service scale with account count, not energy usage. When you spread customer-related costs across this many accounts, the cost per residential customer remains high. The study shows that it costs about $125 per month to keep a residential customer connected to the grid, regardless of how much energy they use.
Third, residential rates have not kept pace with rising fixed costs. The cost study shows that 77% of system costs are fixed. These include power purchase contracts, capital investments, and system maintenance. When rates place too much weight on per-kWh charges, they don’t recover the actual fixed costs. Over time, this gap widens.
Residential usage per customer has also flattened or declined, which makes it even harder for a variable-heavy rate to recover fixed costs.
39%
7%
-6%
6%
-10%
-5%
0%
5%
10%
15%
20%
25%
30%
35%
40%
45%
$-
$0.050
$0.100
$0.150
$0.200
$0.250
$0.300
$0.350
Residential Commercial - Small Medium - Commercial
Primary and Secondary
Service
Large - Commercial
Primary and Secondary
Service
RATE CHANGE
EFFECTIVE RATE ($/KWH)
Figure 2: Cost -of -Service vs. Test Year Effective Rate COS TY Rate
41 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Fourth, current residential rates don’t reflect the cost characteristics of the class. The study found that residential revenue falling short of cost by about $30 million in the test year, requiring an increase of just over 39% to get back to actual cost. That’s the largest gap of any class. Other classes, like medium and large commercial, already pay more than their cost-to-serve and would see lower increases match the cost study.
Finally, residential customers place more pressure on local distribution facilities. The study shows that residential customers make up over half of the sum of maximum demands, which is what drives local distribution costs, including transformers, local circuits, and service lines. The system data is presented in Figure 3. Because these assets are expensive to install and maintain, and because they serve many individual residential connections, this class picks up a large share of the distribution function costs.
Figure 3: PWP Monthly Demand Peaks by Customer Class
Put together, the data shows a simple story. Residential customers use a large share of the system at its most expensive hours, make up the majority of customer accounts, and depend heavily on local distribution assets. At the same time, residential rates haven’t been adjusted to match these cost patterns. The result is a widening gap between what it costs to serve residential customers and what current rates collect.
Rate Making
The process of setting electric utility rates , commonly referred to as rate making , is a structured approach that translates the cost of providing electric service into the rates customers pay. It is both a technical and policy -driven exercise, designed to ensure that rates are equitable, cost -based, and aligned with the City’s broader goals of fiscal responsibility, affordability, and sustainability.
42 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Rate making begins with a COS analysis , where costs are allocated among customer classes. T he next step is rate design, which converts those cost responsibilities into specific rate structures—such as fixed monthly charges, per -kWh energy rates, and demand charges. Rate design must balance several competing objectives: recovering costs, minimizing customer bill impacts, promoting fairness across customer classes, and supporting policy goals such as energy efficiency and clean energy adoption.
Importantly, rate making is not solely a financial exercise. It incorporates policy decisions that reflect community values and strategic priorities. These include:
• Affordability: Avoiding sudden or excessive bill increases by phasing in rate changes over time.
• Equity: Supporting income-qualified customers through targeted rate discounts.
• Sustainability: Encouraging behaviors that reduce peak demand, improve energy efficiency, and support carbon-free electricity. • Transparency and predictability: Ensuring customers understand how rates are set and can anticipate future changes.
The structure of rates also influences customer behavior. For example, time- of-use pricing can encourage customers to shift consumption to off -peak hours, reducing strain on the grid. Similarly, clear and consistent rate signals can promote investment in energy- efficient appliances, electric vehicles, and distributed energy resources.
In Pasadena’s case, the recommended rate adjustment strategy (Alternative 2) reflects a deliberate balance between cost recovery and customer impact. It phases in rate increases over three steps across two fiscal years, capping adjustments to avoid rate shock while maintaining a clear path to full cost recovery. This approach ensures compliance with Proposition 26, which requires that rates not exceed the reasonable cost of service and supports the City’s long-term financial and environmental goals.
Rate Design Alternatives
The recommended rate plan is designed to move each customer class toward full cost of service in a gradual and measured manner. Rather than implementing the full cost -of- service adjustment in a single step, the rate design caps each class’s rate adjustment at no more than 1.5 times the current rate change in any given adjustment period. This approach intentionally moderates bill impacts while maintaining a clear path to cost recovery.
Under this structure, customer classes that are currently under -recovering their cost of service will continue to under-recover during the transition period. That under-recovery is temporary and decreases with each adjustment as rates move closer to the cost- based level identified in the study. The cap prevents sudden or disruptive bill changes, particularly for residential, while still ensuring that rates progress in the correct direction.
This phased approach does not change the underlying cost responsibility of any customer class. The cost-of-service analysis establishes each class’s full cost obligation. The rate 43 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
design simply governs the pace at which rates are adjusted to reach that level. Each rate adjustment is applied proportionally and consistently, reducing cross-subsidies over time rather than perpetuating them.
The approach is compliant with Proposition 26. Proposition 26 requires that charges not exceed the reasonable cost of providing service and that there be a clear relationship between the charge and the service received. The proposed rates satisfy this requirement because they are grounded in a formal cost -of-service study and move each customer class toward its cost -based level once that information is known. Temporary under - recovery during a phased implementation does not violate Proposition 26, as rates are set below, not above, the cost of service and are structured to achieve full recovery over time.
By capping individual rate adjustments and phasing in cost recovery, PWP balances legal compliance, financial sustainability, and customer affordability. This method provides transparency, predictability, and fairness while allowing customers time to adjus t and plan, and it ensures that the electric system remains financially sound as rates are aligned with actual costs.
At Council’s direction, staff could also model additional lower caps ranging anywhere from 1.25 to 1.49. The cap works by limiting the increase by customer class as compared to the system average increase. The residential customer class cost of service results show that they need rate increases greater than the systemwide average, but the caps are a way to gradually phase in the increases. The caps are a ratio of the systemwide increase. For example, regardless of the increase needed for that customer class, a ratio of 1.25 would limit it to 11.9% per phase, because that is
1.25x the systemwide increase of 9.5% in that Fiscal Year. A ratio cap of 1.5 times is presented existing scenarios means that no customer class rate increase can increase by more than 14.3% per phase. This is common practice that moves toward cost recovery by class but gives time for adjustments and movements towards alignment for each customer class.
Since those options would require several weeks, which would also impact the implementation dates, for expediency, the presented alternatives are ones that have already been modeled. Staff has been advised that these are consistent with Proposition 26 defensibility, so other alternatives could be considered but would require advisement from the City Attorney’s Office.
Given the policy direction to use all strategies available to gradually adjust rates, PWP modeled three alternatives for consideration and is requesting further guidance on which alternative is Council’s preference and a summary of which is in Table 1 below.
44 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Table 1: Key Differentiators Between Rate Strategy Alternatives Alternative
1 Alternative
2 Alternative
3 Alternative
4*
Cap on ratio of
increases per phase
1.5 1.5 1.5 ~ 1.25
# of adjustment phases 2 3 3 3
Fiscal Years Impacted FY26 &
FY27
FY26 &
FY27
FY26, FY27
& FY28
FY26, FY27
& FY28+
Meets cost of service
before next study period
Yes Yes No No
Prop 26 Aligned Yes Yes Yes Yes
Use of reserves Low Medium Medium/
High
High
Alternative 1: Immediate Full Cost Recovery – N ot Recommended Alternative 1 establishes a rate plan that would, at the time of proposed adoption, achieve full-cost recovery by customer class with one adjustment. Given the drastic increase required and the implications for customer’s and affordability, staff does not recommend this alternative. Alternative 1 includes an additional $6 million draw down of cash reserves if implemented in March 2026.
Table 2: Percentage Rate Adjustments by Class for Alternative 1 Classes Phase 1 Phase 2 Phase 3
Residential 10.5% 10.5% 10.5%
Commercial - Small 10.1% 6.2% 5.0%
Medium - Commercial 3.9% 5.0% 5.0%
Large - Commercial 3.9% 4.5% 5.0%
Street Lighting 3.9% 7.9% 5.0%
Traffic Signals 10.5% 10.5% 10.5%
Total System 7.0% 7.0% 7.0%
Maximum Rate Increase
Multiple
1.5 1.5
1.5 45
Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Alternative 2: Gradual Full Cost Recovery with options for three adjustments o ver two Fiscal Years.
Alternative 2 provides a strategy for three rate adjustments over two Fiscal Years, the changes recommended to take effect March 2026 (FY26), October 2026 (FY27) and the final adjustment March 2027 (FY27). This alternative is steady and is most aligned with Municipal Services Committee guidance. Alternative 2 includes an additional $32 million draw down of cash reserves if implemented in March 2026, October 2026 and March 2027.
Table 3: Percentage Rate Adjustments by Class for Alternative 2 Classes Phase 1 Phase 2 Phase 3*
Residential 10.5% 10.5% 10.5%
Commercial - Small 10.1% 6.2% 5.0%
Medium - Commercial 3.9% 5.0% 5.0%
Large - Commercial 3.9% 4.5% 5.0%
Street Lighting 3.9% 7.9% 5.0%
Traffic Signals 10.5% 10.5% 10.5%
Total System 7.0% 7.0% 7.0%
Maximum Rate Increase
Multiple
1.5 1.5
1.5 *Phase 3 in March 2027 (FY 2027)
46 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Alternative 3: Gradual Full Cost Recovery with options for three adjustments over three Fiscal Years
Alternative 3 provides a strategy for three rate adjustments over three Fiscal Years, the changes recommended to take effect March 2026 (FY26), March 2027 (FY27) and the final adjustment March 2028 (FY28). Alternative 3 includes an additional $74 million draw down of cash reserves if implemented in March 2026, March 2027 and March 2028. Staff does not recommend this alternative.
Table 4: Percentage Rate Adjustments by Class for Alternative 3 Classes Phase 1 Phase 2 Phase 3*
Residential 10.5% 10.5% 10.5%
Commercial - Small 10.1% 6.2% 5.0%
Medium - Commercial 3.9% 5.0% 5.0%
Large - Commercial 3.9% 4.5% 5.0%
Street Lighting 3.9% 7.9% 5.0%
Traffic Signals 10.5% 10.5% 10.5%
Total System 7.0% 7.0% 7.0%
Maximum Rate Increase Multiple
1.5 1.5
1.5 *Phase 3 in March 2028 (FY 2028)
47 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Alternative 4: Gradual Full Cost Recovery Extending Beyond Study Period, Capping ratio to 1.25 for Residential Customers per phase
This option suggests implementing changes in three steps over three phases (timing is to be determined and has not yet been modeled), allowing customers to adjust gradually while addressing revenue needs more sustainably without shock increases.
The cap of rate increases is set to 1.25 for the Residential customer class but does not reach cost-of-service by the end of FY2027. Future rate increases will be studied and rate impacts may be steeper. This alternative utilizes reserves for delay in revenue collection. Staff does not recommend this alternative.
Table5: Percentage Rate Adjustments by Class for Alternative 4 Classes Phase 1 Phase 2 Phase 3
Residential 8.7% 8.7% 8.7%
Commercial - Small 8.7% 7.0% 6.0%
Medium - Commercial 4.8% 6.0% 6.0%
Large - Commercial 4.8% 5.5% 6.0%
Street Lighting 4.8% 8.7% 6.0%
Traffic Signals 8.7% 8.7% 8.7%
Total System 7.0% 7.0% 7.0%
Maximum Rate Increase Multiple
1.25 1.25
1.25 Customer Bill Impacts
Individual customer bill impacts will vary depending on the customer class and the amount of electricity consumed. Because of the variability of rates, PWP will develop an estimator for customers to understand the impact once one rate plan is decided on.
Below are some impacts using averages for consumption. For comparison purposes, above average usage is also presented for residential customers to give a bit more context on the variability in bill impact due to usage patterns. Timing prohibited PWP with the full pricing development for Alternative 4, and as such, the impact examples are limited to Alternatives 1, 2 and 3.
48 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
Residential Customer Bill Impacts
Single and multi-family residential customers represent nearly 88% of PWP’s customer accounts, whereas they represent 22% of the total consumption for the utility. PWP ensures that the lights are on, and essential electrical services are provided reliably year-round. For comparison purposes, the bill impacts shown in Table 5 below represent an approximation of the average customer, using 500 kWh monthly.
To demonstrate the different impact of the distribution charge structural change, the Tables 5 and 6 below also show a residential customer with approximately “average” monthly consumption with 500 kWh per month and higher-than-average consumption at 1,000 kWh per month. The tables show the impact based on the three alternative strategies to implement rate adjustments.
Table 6: Sample Electric Bills - Monthly (Residential @ 500 kWh) Approximate Bills
Current
Bill March 2026 October 2026 March 2027 March 2028
Alternative 1
$115.01
$150.24 $144.10 $144.10 $144.10
Alternative 2 $113.17 $123.17 $135.11 $135.11
Alternative 3 $113.17 $113.17 $123.17 $135.11
*Amounts represent monthly total bill for a winter month. Energy Services Charge includes projected Power Cost Adjustment based on forecast and is subject to change based on future market conditions.
Table 7: Sample Electric Bills - Monthly (Residential @ 1,000 kWh) Approximate Bills
Current
Bill March 2026 October 2026 March 2027 March 2028
Alternative 1
$251.39
$347.67 $355.94 $355.94 $355.94
Alternative 2 $273.52 $303.25 $337.95 $337.95
Alternative 3 $273.52 $273.52 $303.25 $337.95
*Amounts represent monthly total bill for a winter month. Energy Services Charge includes projected Power Cost Adjustment based on forecast and is subject to change based on future market conditions.
Small Commercial Rate Impacts:
Small commercial customers represent approximately 11% of PWP’s customers and approximately 19% of the total retail power sales (in kWh) per year. Small commercial customers are the backbone of the community that includes establishments such as 49 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
small retail and professional offices, cafes and small restaurants, and small dental or medical offices. An approximation of typical usage is estimated to be around 1,500 kWh per hour. The table 7 below, shows the impact based on the three alternative strategies to implement rate adjustments.
Table 8: Sample Electric Bills - Monthly (Small Commercial @ 1,500 kWh) Approximate Bills
Current
Bill March 2026 October 2026 March 2027 March 2028
Alternative 1
$341.56
$419.88 $390.80 $390.80 $390.80
Alternative 2 $364.73 $385.44 $404.42 $404.42
Alternative 3 $364.73 $364.73 $385.44 $404.42
*Amounts represent monthly total bill for a winter month. Energy Services Charge includes projected Power Cost Adjustment based on forecast and is subject to change based on future market conditions.
Medium Commercial Rate Impacts:
Medium commercial customers represent approximately 1% of PWP’s customers and approximately 23% of the total retail power sales (in kWh) per year. Medium commercial customers include mid-size office buildings (20,000 – 30,000 sq ft), retail stores, groceries, urgent care facilities, veterinary hospitals, restaurants, fitness centers and warehouses. An approximation of typical usage is estimated to be around 15,000 kWh per hour, about ten times that of a small commercial customer. The table 8 below, shows the impact based on the three alternative strategies to implement rate adjustments.
Table 9: Sample Electric Bills - Monthly (Medium Commercial Secondary @ 15,000 kWh)
Approximate Bills
Current
Bill March 2026 October 2026 March 2027
March
2028
Alternative 1
$6,483.80
$7,384.29 $7,680.69 $7,680.69 $7,680.69
Alternative 2 $6,913.70 $7,353.40 $7,801.23 $7,801.23
Alternative 3 $6,913.70 $6,913.70 $7,353.40 $7,801.23
*Amounts represent monthly total bill for a winter month. Energy Services Charge includes projected Power Cost Adjustment based on forecast and is subject to change based on future market conditions.
Large Commercial Rate Impacts:
Large commercial customers represent less than 1% or 130 of PWP’s customers and comprise of approximately 25% of the total retail power sales (in kWh) per year. Large 50 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
commercial customers include hospital, school campuses, supermarkets and departments stores. An approximation of typical usage is estimated to be around 175,000 kWh per hour, about ten times that of a small commercial customer. The table 5 below, shows the impact based on the three alternative strategies to implement rate adjustments.
Table 10: Sample Electric Bills - Monthly (Large Commercial Secondary @ 175,000 kWh)
Current
Bill
Approximate Bills
March 2026 October 2026 March 2027
March
2028
Alternative 1
$37,227.41
$41,954.67 $38,695.51 $38,695.51 $38,695.51
Alternative 2 $38,791.99 $41,588.03 $39,987.64 $39,987.64 Alternative 3 $38,791.99 $38,791.99 $41,588.03 $39,987.64
*Amounts represent monthly total bill for a winter month. Energy Services Charge includes projected Power Cost Adjustment based on forecast and is subject to change based on future market conditions.
To reiterate, customer bill impacts will vary based on customer class and electricity usage as well as seasonally for the residential customers on seasonal flat rates which are variable in the summer vs. winter. PWP’s proposed rates remain competitive with neighboring utilities, though comparisons are influenced by many factors such as differences in infrastructure needs and operating costs.
Alternatives Impacts on Cash or Working Capital Reserves
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. In addition, the reserves offer the ability to manage uncertainties related to construction timelines, project schedules, and financing costs, including interest rate fluctuations. Beyond these functions, the cash reserves serve multiple purposes, such as providing working capital, stabilizing rates to reduce volatility, and funding capital improvements. As depicted in the Figure 4 below, the rate plans maintain the power fund balance at the total minimum working capital reserves. The revenue plan also includes the issuance of $50 million dollars in debt financing.
51 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
$0
$50
$100
$150
$200
$250
$300
$350
$400
FY 2026 FY 2027 FY 2028
Millions
Figure 4: Working Capital
Alt 1 Alt 2 Alt 3 Minimum Reserve Target Reserve
52 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
RE
COMMENDATIONS:
T
he recommended rate adjustment alternative was selected through a comprehensive evaluation, financial modeling, and policy guidance from MSC. The COS Study, conducted in partnership with NewGen, identified a projected revenue shortfall of approximately $67.9 million over two years and revealed significant disparities between current rates and the actual cost to serve various customer classes.
T
he COS analysis showed that residential, small commercial, and traffic signal customers are under-recovering costs, while medium and large commercial customers are over-recovering. Specifically, residential customers require a 39% increase to reach full cost recovery, driven by high fixed infrastructure costs, peak demand contributions, and customer-related service expenses. These findings underscore the need for rate adjustments that realign revenues with cost responsibilities in compliance with Proposition 26.
T
o address this, PWP developed and modeled four rate design alternatives, each balancing cost recovery, customer affordability, reserve impacts, and legal compliance.
The alternatives varied in the number of adjustment phases, the cap on rate increases, and the timeline for achieving full cost recovery.
A
lternative 2 was selected as the recommended approach because it:
• Aligns with MSC guidance for a steady, phased implementation over two fiscal years (FY26 and FY27).
• Achieves full cost recovery before the next rate study period, ensuring financial sustainability.
• Moderates customer bill impacts by capping rate increases at 1.5 times the current rate change per phase.
• Maintains reserve levels above policy minimums, supporting operational and capital needs without excessive reliance on reserves.
• Complies with Proposition 26, ensuring rates are based on actual costs and structured to achieve full recovery over time.
S
taff believes this approach provides a balanced path forward, reducing cross-subsidies while allowing customers time to adjust. It supports the City’s goals of fiscal responsibility, infrastructure modernization, and clean energy transition, and reflects community input gathered through extensive public engagement.
C
omprehensive Light and Power Rate Ordinance Recommendations for Restatement and Modernization
S
taff recommends a restatement because the current rates ordinance has become too unwieldy to manage through piecemeal amendments. Over time, layers of changes, cross-references, and outdated language have made it hard for staff, customers, and decision makers to read and understand. A restatement lets us reorganize the entire structure, integrate all prior amendments, remove inconsistencies, and modernize the policy in a clear and coherent format. This approach improves transparency, supports 53 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
com
pliance, and gives the public a complete, readable ordinance instead of another round of patchwork edits.
Det
ails were summarized and stated as in Attachment A. Attachment C is the redlined version of the proposed edits published for transparency and for policy guidance.
Im
plementation Timeline
PW
P is recommending that a public hearing be set for February 9, 2026, to receive comments on the recommended adjustments to the electric rates. Following the City Council’s action to set a date for the public hearing, a notice will be mailed to all electric system customers that includes the recommended rate adjustments and provides information regarding the public hearing. Table 6 outlines the approximate timeline and implementation schedule for the proposed rate actions.
Tab
le 11: Timeline
COUNCI
L POLICY CONSIDERATION:
The r
ecommendations are consistent with the City Council’s goals to maintain fiscal responsibility and stability; improve, maintain, and enhance public facilities and infrastructure; and increase conservation and sustainability.
Date Action Item
January 2026 Mail public hearing notice
January 2026-February 2026 Customer Outreach and Education February 9, 2026 Electric Rates Public Hearing
February 23, 2026 First Reading of Updated Electric Rate Ordinance March 2, 2026 Second Reading of Updated Electric Rate Ordinance March 1, 2026 or as soon as
practicable thereafter Effective Date of First Rate Action 54 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
ENVIRONMENTAL ANALYSIS:
The es
tablishment of a date to conduct a public hearing for the consideration of electric rate adjustments and the drafting of related resolutions and ordinance amendments are administrative actions that would not cause either a direct physical change in the environment or a reasonably foreseeable indirect physical change in the environment.
Therefore, the proposed actions do not constitute a “project” subject to CEQA, as defined in Section 21065 of CEQA and Section 15378 of the State CEQA Guidelines.
Since the action is not a project subject to CEQA, no environmental document is required. Furthermore, the recommended electric rate adjustments themselves would be statutorily exempt from CEQA. Section 15273 of the State CEQA Guidelines identifies a statutory exemption for "Rates, Tolls, Fares, and Charges" and states (in part) that:
a. CEQA does not apply to the establishment, modification, structuring, restructuring, or approval of rates, tolls, fares, or their charges by public agencies which the public agency finds are for the purpose of:
1. Meeting operating expenses, including employee wage rates and fringe benefits,
2. Purchasing or leasing supplies, equipment, or materials,
3. Meeting financial reserve needs and requirements,
4. Obtaining funds for capital projects, necessary to maintain service within existing service areas, or
5. Obtaining funds necessary to maintain such intra-agency transfers as are authorized by city charter.
55 Set a Public Hearing for the Recommended Electric Rate Adjustments January 12, 2026
FISCAL IMPACT:
The
estimated cost to mail information about the public hearing and recommended rate increases to all City of Pasadena electric customers is approximately $30,000. Funds are available in the Light and Power Fund.
The r
ate increases are expected to generate incrementally between $17 million and $24 million depending on alternative enacted. The incremental revenues will be used to offset increased O&M and capital costs of the electric system.
Atta
chment A: December 9,2025 Municipal Services Committee Agenda Report and attachments.
Attachment B: Draft Cost-of-Service Report
Attachment C: Redline of Light and Power Rate Ordinance Chapter 13.04 Attachment D: Rate Schedule Alternative 3
Attachment E: Revised Rate Schedule Alternatives 1 and 2 Respectfully submitted,
______
_____________________
DAVID M. REYES
General Manager
Water and Power Department
Prepared by:
______
_____________________
Lynne Chaimowitz
Assistant General Manager
Water and Power Department
Appr
oved by:
______
_____________________
MIGUEL MÁRQUEZ
City Manager
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PASADENA WATER AND POWER
MEMORANDUM
The fol
lowing document is section 2 of the Electric Rate Study, this next phase of the study evaluates how current electric rates align with the actual costs of providing service to each customer class. This next step within the rate-making process comes after determining the system revenue requirement and then establishes a revenue requirement for each customer class, which is determined based on the specific costs to serve that class.
The CO
S analysis reveals that 77% of PWP’s costs are fixed, driven by infrastructure, power supply contracts, and customer service operations. Only 23% are variable, such as fuel and purchased power. This fixed-cost structure underscores the importance of rate design that ensures stable revenue recovery.
Key f
indings include:
• Residential customers currently under-recover by approximately 39%, while Medium Commercial c
ustomers slightly over-recover.
• The cost
to connect to the PWP system, regardless of energy usage, is $125/month for R
esidential customers, reflecting the infrastructure and service readiness
costs.
The COS framework also introduces a new Electric Vehicle (EV) customer class, laying the groundwork for future rate structures tailored to EV charging needs.
This analysis will inform the next phase of the study: rate design, which aims to align rates with actual service costs, promote equity, and support long-term financial sustainability.
Attachment B: Cost of Service Report
111
Ec
onomics | Strategy | Stakeholders | Sustainability PWP Electric Rate Study Final Report Section 3
ELECTRIC COST-OF-SERVICE
After determining the system revenue requirement, a revenue requirement for each customer class was determined based on the specific costs to serve each class. Customer class revenues are compared to class revenue requirements to evaluate the current rate ’s abilities to fully recover costs. NewGen analyzed the cost to serve each customer class based on the revenue requirement developed in Section 2.
Once completed, the CO S results indicate the degree to which existing rates recover the costs to serve customers. The COS results are then used to design new electric rates.
The COS analyses relied on the following key supporting data and analysis:
Revenue requirements and revenues based on current rates. Total system and customer class demand and energy requirements. Actual and assumed customer service characteristics.
Information obtained from customer accounts and records.
Cost-of-Service Process
NewGen performed an analysis of the cost to serve each customer class based on the revenue requirement developed in Section 2. There are three steps in developing the COS for each customer class, as illustrated in steps 2–4 in Figure 3-1 below.
Figur
e 3-1. Cost-of-Service Process
Step 1 is the development of the revenue requirement as explained in Section 2.
Step 2 is the functional unbundling of the revenue requirement. Functional unbundling provides detailed descriptions of the utility’s revenue requirement by core utility function. Accounting 112
i
nformation is provided by PWP budget accounts. If an item has been adjusted, the amount of the adjustment is identified with an associated supporting calculation. Once the detailed revenue requirement has been established, the amount is assigned to the production, transmission, distribution, and customer functions. Assignments are made either through direct assignments or other allocation methodology. The results of the Component A analyses for each function of the revenue requirement are expressed on a functional basis.
Step 3 is the classification and sub- functional unbundling of the revenue requirement. Sub - functionalizing the production, transmission, distribution, and customer functions developed in Step 2 provides additional detail and accuracy to PWP’s costs. Additionally, costs are classified as demand related, energy related, customer related, or a direct assignment. Like functionalizing, sub- functionalization is accomplished either through direct assignments or other allocation methodology. Specific allocation factors are found at the bottom of each sub -function worksheet.
Step 3 analyses result in PWP’s revenue requirement expressed on a sub -functional basis for each cost classification (e.g., Production Demand or Production Energy Costs).
Step 4 is the allocation of the classified and sub-functionalized costs to the customer classes. Using the information developed in Step 3, the sub -functionalized and classified revenue requirement is allocated to each of the rate classes using various customer class allocation methodologies. These allocation methodologies or allocators are developed in alignment with the cost classification. For example, production demand costs are allocated utilizing the customer’s contributions to system demand such as four-coincident peak (4CP) or the highest four months of PWP system peaks.
Once completed, the COS results indicate the degree to which existing rates recover the costs to serve customers. These results are then used in designing new electric rates.
Functionalization
PWP’s electric rates have been unbundled into four functions: production, transmission, distribution, and customer. Descriptions of each utility function are below.
Production Function
The production function consists of costs associated with operating and maintaining electric generation facilities and making capital investments, as necessary. This function also includes purchased power, fuel, and power labor costs.
Transmission Function
The transmission function consists of costs associated with transmitting power from generation plants or the CAISO markets to PWP’s local load. These costs include market transmission costs, operating and maintaining transmission lines and related infrastructure , and making capital investments, as necessary.
Distribution Function
The distribution function consists of costs associated with operating and maintaining the localized distribution portion of the electric grid and making capital investments, as necessary. The distribution facilities deliver power to the retail customers after it has been transmitted. This includes primary and secondary voltage distribution lines, distribution poles, underground lines, customer service connections, meters, and lighting -related assets. PWP has 1,660 miles of overhead and underground lines.
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Customer Function
The customer function consists of costs associated with operating and maintaining the customer related facilities to meet customer support needs. This includes, but is not limited to, customer service, and billing and collection. PWP services approximately 68,000 electric customers, and over 59,000 are in the Residential Service class.
Functionalized Revenue Requirement
The revenue requirement was “unbundled” into the four functional areas of the system: production, transmission, distribution, and customer. The results of the functional unbundling are summarized in Table 3-1.
Table 3-1
Functionalized Revenue Requirement
Function Revenue $/kWh(1) % of Total Requirement
Production $127,296,677 $0.1224 49%
Transmission $12,494,313 $0.0120 5%
Distribution $105,410,519 $0.1013 41%
Customer $14,355,356 $0.0138 6%
Total $259,556,865 $0.2496 100%
(1) Based on Test Year energy sales of 1,040,083,319 kWh.
The production function, including P WP’s operating expenses and purchased power, represents 49% of the revenue requirement. The distribution function is the second largest cost center, representing 41% of the revenue requirement. The customer function is the third largest cost center, representing 6% of the revenue requirement. The remaining 5 % of the revenue requirement is associated with the transmission function.
Classification
System costs can be classified into four generally accepted rate -making cost classifications:
(i) demand or fixed costs, (ii) energy or variable costs, (iii) customer- related costs, and (iv) directly assignable costs. To provide a reasonable basis for the assignment or allocation of total revenue requirements (costs) to each customer class, costs for each function in the electric system have been analyzed and classified into four categories. P WP’s functional costs were classified on the following basis:
1. Demand Costs – Capacity (fixed- or demand-related) costs are those costs incurred to maintain a utility system in a state of readiness to serve, enabling it to meet the total combined demands of its customers. Capacity costs include the portion of O&M expenses, debt service, capital expenditures, and other costs that are generally fixed and do not vary materially with the quantity of usage, or that cannot be designated specifically as a customer or variable cost.
2. Energy Costs – Energy or variable costs are costs that vary directly with energy usage, including such items as fuel, energy-related purchased power, and a portion of O&M expenses. 114
3. Customer Costs – Customer costs are those costs directly related to the number and type of customers, such as customer accounting, billing, service connections, and meter -related expenses.
4. Direct Assignment Costs – Direct assignment costs are those costs that are readily identifiable and applicable to a customer or customer class (e.g., street lighting).
Once the costs within each function are assigned to each service category, the demand, energy, customer, and direct assignment component of each service is calculated. As seen in Table 3 -2, three major cost categories (demand, energy, and customer) cover most of all functional costs. This breakdown of demand, energy, customer, and direct assignment costs is later applied to each customer class to facilitate the electric system rate design, as provided in Section 4. The classified revenue requirement is shown below in Table 3-2.
Classified Revenue Requirement
In total, 23% of PWP’s total revenue requirement is energy-related or variable costs. The remaining 77% of the revenue requirement is fixed in nature and classified as demand, customer, or directly assigned to particular customer classes. Table 3-2 shows additional details regarding the classified costs within each function and classifies the costs within each.
Table 3-2
Classified Revenue Requirement
Classification Revenue $/kWh(1) % of Total(2) Requirement Production
Demand $80,394,286 $0.0773 31%
Energy $46,902,391 $0.0451 18%
Subtotal $127,296,677 $0.1224 49%
Transmission
Demand $0 $0.0000 0%
Energy $12,494,313 $0.0120 5%
Subtotal $12,494,313 $0.0120 5%
Distribution
Demand $88,989,628 $0.0856 34%
Customer $12,725,008 $0.0122 5%
Other $3,695,883 $0.0036 1%
Subtotal $105,410,519 $0.1013 41%
Customer
Customer $14,355,356 $0.0138 6%
Subtotal $14,355,356 $0.0138 6%
Demand $169,383,914 $0.1629 65%
Energy $59,396,704 $0.0571 23%
Customer $30,776,248 $0.0296 12%
Total Costs $259,556,865 $0.2496 100%
(1) Based on Test Year energy sales of 1,040,083,319 kWh. (2) Percentages may not add to 100% due to rounding. 115
Allocation
Based upon actual and assumed customer service characteristics, NewGen developed various factors for use in allocating the adjusted revenue requirements to individual customer classes.
These allocation factors reflect accepted rate -making principles and were based upon sufficiently distributed embedded cost allocation procedures. The following summary describes the specific allocation factors used in the Study.
Once revenue requirements are classified, they are allocated to the individual customer classes based on customer usage characteristics. For the system and customer classes, we have developed demand -related, energy -related, customer -related, and direct as signment allocation factors as described below.
Demand Allocations
Demand allocation refers to the basis on which capacity -related costs are distributed or assigned (i.e., allocated) among the various customer classes for the purpose of determining the COS for each class. The demand allocation factors that were developed reflect the cost responsibility of the various customer classes with respect to their contribution to demand -related system characteristics (i.e., contribution to monthly peak demand).
For example, monthly coincident peak demand by customer class reflects the customer class’s contribution to the monthly system peak demand. The peak demand is often referred to as the “Coincident Peak” (CP) because it is the amount of total load from all customers collectively at the same time (coincident with each other).
Non-coincident peak (NCP) demand reflects the customer class’s peak demand, whenever that may occur, and does not have to coincide with the overall system peak. The NCP demand allocation method is based on the theory that demand costs are strongly influenced by the highest demand of each customer class, regardless of when that class peak demand occurs. NCP demand allocators are primarily used to allocate distribution-related costs because the design of these facilities is more consistent with the demand of the classes, rather than the demand of the entire system. Coincident and non- coincident demands are typically calculated considering a one, three, four, or twelve - month period.
The data used to calculate CP and NCP were developed utilizing PWP’s billing database and Proxy Advanced Metering Infrastructure (AMI) from a nearby utility with similar usage profiles. AMI meters record energy usage on a 15-minute or hourly basis which can be used to pinpoint each class’s contribution to system or local peaks. These system and local peaks are the key driver for PWP’s costs to deliver electric service. Figure 3 -2 shows the customer class contributions to P WP’s monthly system peak demands, or the CPs.
116
Figure 3-2. Monthly PWP System Peak Demands
Production Demand Allocation
As seen in Figure 3 -2, the PWP system has a dramatic peak during the summer months of June through September. This system peak is what PWP must design, construct, and operate their generation and transmission system to serve. However, as PWP must plan and build infrastructure to supply production services for those four peak months, those costs and assets may not be utilized year-round to meet the other eight months of system demands. As such, PWP’s production functionalized costs were sub -functionalized into a base load PWP -owned and peak load costs.
Subsequently, the base load costs which support year-round system peaking needs are allocated to customer classes on a 12 CP method. Similarly, the peak load costs associated with meeting summer peaking demands are allocated to the customer classes using the 4CP method. This is an appropriate cost allocation methodology for the southern California climate and load profile as it captures the class-level contributions to the peak system demand in the summer months but also recognizes some costs and assets are used year-round.
Distribution Demand Allocation
Similarly, distribution costs are designed to meet the maximum demands of the localized system or customers, so 4 non-coincident peak (4 NCP) and the sum of maximum demands (SMD) allocation factors are used. An NCP allocator is typically used to allocate distribution costs as these facilities are sized to meet localized peak demands rather than the system peak demand. The 4 NCP method was used to allocate the distribution system demand -related costs associated with substations, primary lines, and secondar y lines . The SMD was used to allocate demand costs related to distribution transformers near customer service locations. The SMD is reflective of the localized demands customers place on the system at and near the meter. For customer classes that are billed for demand, the SMD represents annual measured demand.
-
50,000
100,000
150,000
200,000
250,000
300,000
350,000
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
System Peak Demand (kW)
PWP Monthly Peaks
Residential Commercial - Small
Medium - Commercial Pri. and Sec. Large - Commercial Pri. and Sec.
Street Lighting Traffic Signals
117
Table 3-3 compares the various demand allocators utilized in the Study.
Table 3-3
Demand Allocation Factors
Customer Class 4 CP 4 NCP SMD
Residential 37.65% 43.41% 52.20%
Commercial - Small 13.45% 11.80% 13.77%
Medium - Commercial
Primary and Secondary
Service
21.95% 19.19% 16.10%
Large - Commercial Primary
and Secondary Service 26.71% 24.58% 17.31%
Street Lighting 0.00% 0.93% 0.59%
Traffic Signals 0.24% 0.09% 0.04%
Total 100.00% 100.00% 100.00%
Energy Allocations
Energy allocation factors are the basis for allocating costs or expenses classified as variable or energy related and are assumed to vary directly with kWh sales. Energy -related costs classified as variable include fuel, variable O&M costs, and purchased power. Typically, net energy for load (NEFL), or the energy necessary to supply each customer class, is used to allocate these types of costs to individual customer classes. NEFL is also sometimes called adjusted metered load or energy at generator, as it takes into consideration energy losses that occur on the transmission and distribution systems between the power generation facility and the customer’s meter. For PWP all transmission costs are energy related as a result, NEFL was used as the allocation method. Table 3- 4 lists the energy allocation factors utilized in the Study.
Table 3-4
Energy Allocation Factors
Customer Class Net Energy
for Load
Residential 31.03%
Commercial - Small 13.32%
Medium - Commercial Primary
and Secondary Service 24.87%
Large - Commercial Primary
and Secondary Service 29.76%
Street Lighting 0.90%
Traffic Signals 0.12%
Total 100%
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Customer Allocations
Customer costs are defined as those costs related to the number of customers and the type of service required. Included in the customer -related costs are the costs associated with meter reading, customer service, sales, billing, collection, and other cust omer-related activities. The customer allocation factors were largely based on the number of customers in each class.
At times in a COS study, certain customer-related costs can be allocated to the various customer classifications based on a weighted customer allocation factor. Weighting reflects that servicing certain types of customers requires more effort and expense than other types of customers. For PWP, weighting factors were not required, nor developed, based on discussions with PWP as there were limited customer service related costs . Public benefits costs were also included in this function; however, they were allocated based on the revenue requirement of each class to reflect the cost causation of the public benefit charge mechanism.
Cost-of-Service Results
The COS process is an industry -accepted framework that assigns costs to customer classes. This process determines the “cost to serve” each customer class within a utility.
Fixed and Variable Costs
Electric utility costs are typically characterized as either fixed or variable; fixed costs are those that do not change with the production of electricity, whereas variable costs are related to the amount of electricity produced and/or purchased. PWP’s
fixed costs are 77 % of the total revenue
requirement. The remaining 23 % of costs are
variable and include fuel, purchased power, and
variable O&M. PWP’s fixed costs are higher than
some industry peers due to the number of power
supply contracts or power purchase agreements
that have fixed components to the contracts or
cost structure. These contracts also provide
PWP physical assets and hedges in the CAISO
market to mitigate market risks to customers.
Fixed Cost to Connect to the PWP System
As stated above, the test year fixed costs are
77% of the total revenue requirement. There is a
cost for each customer to attach to the P WP
system whether or not that customer uses any
energy. As shown in Table 3-5, it costs $125 per month for each Residential customer to be attached to the PWP system, whether they use 0 kWh or 1,000 kWh. The fixed cost per a customer for each class is displayed below.
Figure 3-3. Test Year Fixed and Variable Costs
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Table 3-5
Fixed Cost Per Customer to Connect to the PWP System
Function Residential Small -
Commercial
Medium -
Commercial
Large -
Commercial
Street
Lighting
Traffic
Signals System
Power Supply $40 $121 $1,946 $16,928 $2,637 $123 $99 Transmission $0 $0 $0 $0 $0 $0 $0
Distribution $56 $118 $1,857 $15,306 $26,782 $33 $109 Customer $29 $36 $199 $903 $29 $29 $38
Total
$/Month/customer $125 $275 $4,002 $33,137 $29,448 $185 $246
The power supply and distribution fixed costs represent the demand-related costs of infrastructure and expenses translated into a monthly cost per customer. The customer- related costs are associated with customer service and customer accounting serving the classes. As seen in the table it costs PWP a minimum of $125 per customer per month to provide service, and that cost does not vary with the amount of energy or kWhs consumed.
Cost-of-Service Results by Class
Table 3-6 summarizes the total cost of service for each customer class. These costs are delineated into the discrete classified costs within each function. Please note the Electric Vehicle (EV) customer class shown in Table 3-6 is a new customer class that does not currently have any customers or billed consumption. Existing services to EV charging stations or locations are provided under an existing applicable commercial class such as Medium or Large Commercial tariff rates. As there are no customers, there are no revenues. The EV cost of service will be used in supporting the tracking of costs for these types of sites and services in addition to the development of new rates and tariffs focused on serving EV charging locations and loads.
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P
WP Electric Rate Study Final Report 10
Table 3-6
Cost-of-Service Results by Class
Classification Residential Small - Commercial Medium -
Commercial Large - Commercial Street Lighting Traffic
Signals
EV - Electric
Vehicle Total
Production
Demand $28,404,624 $11,009,880 $18,113,051 $22,495,897 $81,736 $289,097 $0 $80,394,286 Energy $14,553,395 $6,247,648 $11,666,870 $13,956,636 $421,047 $56,794 $0 $46,902,391 Subtotal Production $42,958,019 $17,257,528 $29,779,921 $36,452,534 $502,784 $345,891 $0 $127,296,677 Transmission
Demand $0 $0 $0 $0 $0 $0 $0 $0
Energy $3,876,874 $1,664,309 $3,107,934 $3,717,904 $112,163 $15,129 $0 $12,494,313 Subtotal Transmission $3,876,874 $1,664,309 $3,107,934 $3,717,904 $112,163 $15,129 $0 $12,494,313 Distribution
Demand $39,683,928 $10,773,454 $17,283,753 $20,340,010 $830,254 $78,229 $0 $88,989,628 Customer $11,098,069 $1,423,515 $145,370 $20,756 $484 $36,814 $0 $12,725,008 Other $0 $0 $0 $0 $0 $0 $3,695,883 $3,695,883
Subtotal Distribution $50,781,997 $12,196,969 $17,429,123 $20,360,766 $830,738 $115,042 $3,695,883 $105,410,519 Customer
Customer Service $2,309,645 $974,724 $974,724 $974,724 $101 $7,661 $0 $5,241,579 Customer Accounting $5,375,670 $689,521 $704,144 $201,076 $235 $17,832 $0 $6,988,476 Meter Reading $1,796,618 $230,447 $23,533 $3,360 $78 $5,960 $0 $2,059,996 EV - Electric Vehicle $0 $0 $0 $0 $0 $0 $65,305 $65,305 Subtotal Customer $9,481,933 $1,894,691 $1,702,401 $1,179,160 $414 $31,453 $65,305 $14,355,356 Total Costs (Revenue
Requirement) $107,098,823 $33,013,498 $52,019,379 $61,710,363 $1,446,098 $507,516 $3,761,188 $259,556,865 Summarized Total
Demand $68,088,552 $21,783,334 $35,396,804 $42,835,907 $911,990 $367,326 $0 $169,383,914 Energy $18,430,269 $7,911,957 $14,774,804 $17,674,540 $533,210 $71,924 $0 $59,396,704 Customer $20,580,002 $3,318,207 $1,847,772 $1,199,916 $898 $68,266 $3,761,188 $30,776,248 Total $107,098,823 $33,013,498 $52,019,379 $61,710,363 $1,446,098 $507,516 $3,761,188 $259,556,865 121
PWP Electric Rate Study Final Report 11
Cost-of-Service Results Compared to Current Revenue
To evaluate the ability of current rates to adequately recover the COS, NewGen calculated revenues based on Test Year billing data and current rates, then compared the resulting revenues to the COS for each customer class. The results of the comparison are shown in Table 3 -7. This represents a snapshot of the test year revenue requirements which include costs for FY 2025/26 and FY 2026/27 compared to the current rates.
At a system level, current rates and revenues require a one-time 13.9% increase to collect the full COS. Also shown in Table 3-7 is the approximate percentage increase/(decrease) in each customer class's revenues necessary to fully recover the COS for the test year. The percentage increase or decrease shown in the table provides guidance for future rate design without subsidization and with full rate revenue recovery.
Table 3-7
Current Rate Revenues Compared to Cost-of-Service
Class/Service Revenue
Requirement
Estimated Test
Year Revenues
with Current Rates
Projected Over
(Under) Recovery
COS Rate Increase
(Decrease) Needed
(%)
Residential $107,098,823 $76,972,473 ($30,126,350) 39.14% Commercial - Small $33,013,498 $31,068,587 ($1,944,911) 6.26% Medium - Commercial
Primary and
Secondary Service
$52,019,379 $54,463,401 $2,444,022 -4.49%
Large - Commercial
Primary and
Secondary Service
$61,710,363 $62,371,800 $661,436 -1.06%
Street Lighting $1,446,098 $2,721,576 $1,275,478 -46.87% Traffic Signals $507,516 $392,553 ($114,963) 29.29%
EV - Electric Vehicle $3,761,188 $0 ($3,761,188) 0%
Total $259,556,865 $227,990,390 ($31,566,476) 13.85%
(1) EV customer class is not yet in-service or available. Costs are being tracked for the development of future classes and tariffs. As such, no revenues or COS rate changes are identified at this time.
The comparison of the COS results to the current revenues informs the eventual rate design and strategy for FY 2025/26 and beyond. While the COS results represent a one-time rate adjustment to achieve the test year revenue requirement, PWP has multiple options regarding the implementation of rates and the potential to phase-in the rate changes over multiple years. By phasing in rate changes over multiple years, PWP can reduce the potential bill change and increase impacts to customers.
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Section 13.04.010 Short title.
This chapter shall be named and may hereafter be designated as "the light and power rate ordinance."
13.04.020 Definitions.
A. Abbreviations.
1. "K.W.H.," as herein used, indicates and “Apparent power” means "kilowatt hours."
2. "K.W.," as herein used, means "kilowatt," anthe total electrical unit of power.
3. "H.P.," as herein used, means "horsepower," a mechanical unit of power.
A. B."Air conditioning apparatus" is an electrically driven mechanically operated compressed-refrigerant-type cooler of sufficient capacity required to properly cool that portionsupply a load, regardless of how efficiently the enclosed rooms normallypower is used for business purposes. .
B. “Customer charge” is a fixed monthly charge regardless of energy use. It is generally associated with services such as billing, customer service, meter reading, and connection to the grid.
C. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month.
C."Billing demand is determined to the nearest kW.
B.D. “Department," "Pasadena Water and Power" or "PWP," as herein used, means the "municipal water and power department of the cCity of Pasadena." .
D. "Electric water heater" must not exceed the following limitations. The base heating element shall be controlled by a thermostat located near the bottom of the tank and shall not exceed a total rating of 2500 watts or 50 watts per gallon for tanks over 50-gallon capacity. A booster heating element will be allowed in the tank and shall not exceed a total rating of 2500 watts or 50 watts per gallon for tanks over 50-gallon capacity when individually controlled by a separate thermostat set to cut in only when the temperature of the top ⅓ of the tank capacity is 20 degrees Fahrenheit below the temperature setting of the bottom thermostat. Large storage-type tanks are recommended which have heavy insulation.
E. E. “Distribution charge” is a usage-based charge generally associated with the cost of delivering electricity from the substations, including operation and maintenance costs, capital investment and debt service.
F. “Electric Utility Rate Resolution” means a schedule of pricing for all fees, penalties, refunds, reimbursements, and charges of any kind collected by the Department and adopted by City Council.
G. “Energy services charge” (including power cost adjustment) is a usage-based charge generally associated with the solely variable cost of generating the actual amount of electricity consumed, measured in kilowatt-hours.
H. "Greenhouse gas" or "GHG" is a collective term for those gases that reduce the loss of heat from the earth's atmosphere, and thus contribute to global warming and climate change.
I. “Grid access charge” is a fixed monthly charge generally associated with the fixed costs of connecting to and maintaining the electric grid, regardless of their energy consumption.
J. “Holidays” refer to days recognized by the North American Electric Reliability Corporation (NERC) that typically impact electricity demand and pricing. Holidays include New Year’s Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). These holidays may be updated from time to time based on NERC guidelines.
K. “Horsepower” or "hp," as herein used means a mechanical unit of power.
L. “Interval Read Capable Meter” refers to electric meters that can record and transmit energy usage data at regular, predefined intervals, rather than providing a cumulative total once per billing cycle.
Attachment C: Redline of Chapter 13
123
M. “kilowatt” or "kW" is a unit of power equal to one thousand watts. It measures the rate at which energy is used or produced.
N. "kWh" as herein used, indicates and means "kilowatt hours." A kWh is a standard unit of energy used to measure electricity consumption. It represents the amount of energy used when a device that consumes 1,000 watts (or 1 kilowatt) operates for one hour.“
O. “megawatt” or "MW" is a unit of power equal to one million watts. A MW is a unit of power that measures the rate at which energy is used or produced.
P. "MWh" as herein used, indicates and means "megawatt hours." A MWh is a standard unit of energy used to measure electricity consumption. It represents the amount of energy used when a device that consumes one million watts and operates for one hour.
Q. “Net deficit electricity” means the electricity consumed by a customer-generator, as measured in kWh, exceeds electricity generated by that eligible customer-generator.
R. “Net neutral electricity” means the electricity consumed by a customer-generator, as measured in kWh, equals the electricity generated by that eligible customer-generator.
S. “Net surplus electricity” means the electricity generated by a customer-generator, as measured in kWh, exceeds the amount of electricity consumed by that eligible customer-generator.
T. "Portfolio content category one (PCC1)" means an eligible renewable energy resource interconnected or scheduled into a California balancing authority at the same time of generation pursuant to Sections 399.16(b)(1), 399.16(c)(1) and 399.30(c)(3) of the California Public Utilities Code.
C.U. "Power equipment" means electrical machinery such as motors, welding machines, battery chargers, radio- sending and X-ray equipment will normally be operated on a separate power meter. However, some power equipment, especially smaller size equipment, may be added and operated on the regular lighting meter, provided the starting and stopping or fluctuating load characteristics do not cause objectionable voltage fluctuations in any service rendered by the dDepartment. The use of power equipment on lighting or combination meters must have the approval of the general manager of the dDepartment.
F. Power:
1. Real Power. The work producing part of "apparent power" or rate of supply of energy—usually expressed in kilowatts (kW).
V. 2.“Power Factor“ means the ratio of real power (kilowatts) to apparent power (kilovolt-amperes) for any given load and time (maximum value = 1.0). Power Factor = Real Power/Apparent Power W. “Public benefit charge” is a state-mandated nonbypassable, usage-based public benefit charge to fund assistance programs, energy efficiency and renewable energy projects.
D.X. “Reactive Power. The“ means the portion of "apparent power" which does no work but must be supplied to power equipment, such as motors—usually expressed in kilovars (kvar).
Y. 3.“Real Power Factor. The ratio” means the work producing part of real power (kilowatts) to "apparent power (kilovolt-amperes) for any given load" or rate of supply of energy—usually expressed in kilowatts (kW).
Z. "Renewable energy credit" or "REC" means a certificate of proof that one unit of electricity was generated by an eligible renewable energy resource. RECs are accumulated on a kWh basis and one REC represents the green attributes associated with the generation of one MWh from the electric generation facility.
AA. “Reservation Charge” is the monthly demand charge applied to the customer’s total nameplate capacity (kW) CC.
BB. "Retail customers" means customers who choose PWP as their energy supplier.
CC. "System energy sales" means the estimated total energy sales delivered to all customers. 124
DD. “Time-of-Use” or “TOU” is electricity pricing where the price of electricity varies depending on the time (maximum value = 1.0). of day, day of the week, and season. Electricity is more expensive during peak demand periods.
EE. “Transmission services charge” is a usage-based charge generally associated with the cost of delivering electricity from the generating plants to our sub-stations.
13.04.030 Light and power rate standards.
The rates to be charged and collected for furnishing and delivering electrical energy, and the terms, provisions and conditions respecting such rates, delivery of electrical energy and for service supplied by the municipal light and power department of the city to customers served by the departmentDepartment shall be fixed as set forth in the following sections.
13.04.031 Pricing, pricing periods, and seasons
A. Pricing: The pricing for all fees, penalties, refunds, reimbursements, and charges of any kind collected by the Department pursuant to the provisions of this chapter shall be specified in the Electric Utility Rate Resolution, as amended by the Council from time to time. Whenever applicable throughout this chapter, reference shall be made to the Electric Utility Rate Resolution in lieu of any reference to specific fee amounts.
B. Seasonal Periods: Pricing varies between high and low demand months and the associated costs to provide services during those time periods. Prior to Interval Read Capable Meter Implementation, there are two time- period blocks on-peak and off-peak defined in the Electric Utility Rate Resolution. After Interval Read Capable Meter Implementation, there will be three time- period blocks, on-peak, off-peak and critical peak.
C. Prior to Interval Read Capable Meter implementation: “High Season” means the period of June through September and “Low Season” means the period of October through July.
D. After Interval Read Capable Meter Implementation: “High Season” means the period of July through October and “Low Season” means the period of November through June.
E. Time-of-Use Periods. “Time-of-Use” or “TOU” periods reflect when systems costs are high or low to signal to customers to shift usage to times that are better for the overall electric system and provide pricing for service components which varies by time of day and season of the year. The three time-of-use periods are “on-peak”, “off-peak” and “critical-peak” that vary in their times based on electric system energy costs.
13.04.040 Residential single-family service. (Schedule R-1) The raterms and conditions of services hereunder shall be as provided by Schedule R-1, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE R-1
Residential Single-Family Service
A. A.Applicability. Applies to separately metered single-family dwellings and to individual family accommodations. with single phase 120/240-volt or 120/208-volt, and three-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service. Motors with more than 150 amps locked motor are not served under this schedule.
B. Character of Service Furnished. Single phase 120/240-volt or 120/208-volt, and 3-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service.
C. Conditions of Use. Motors with more than 150 amps locked rotor are not served under this schedule.
D. Customer Rates. Customers shall pay the sum of the following charges (1) customer charge, grid access charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, (5) transmission services charge, and energy services charge as specified below. 125
B. 1.Customer Charge and Grid Access Charge. Customers taking service under Schedule R-(6) public benefit charge. The minimum monthly charge shall be equal to the sum of the (1 shall pay a) customer charge and a(2) the grid access charge during the billing month as follows: .
B.C. Customers taking service under Schedule R-1 shall have two energy rate option for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed.
Effective July 2017:
Customer Charge Per Meter Per Month
$8.96
Effective July 2019:
Grid Access Charge Per Meter Per Month
$4.50
2. Distribution Charge. Customers taking service under Schedule R-1 shall pay a distribution charge based on kWh used during the billing month as follows:
Effective July 2017:
Usage $ per kWh
First 350 kWh per month $0.01889
Next 400 kWh per month $0.14673
All additional kWh per month $0.10706
3. Transmission Services Charge. Customers taking service under Schedule R-1 shall pay a transmission services charge for each kWh delivered to the in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule R-1 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07073
Winter $0.06147
4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.14750
Summer Off-Peak $0.04750
Winter On-Peak $0.11150
Winter Off-Peak $0.05100
This option is subject to meter availability. The customer shall be responsible for the cost of installing the metering equipment required for this service.
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4.3 Power Cost Adjustment: Power cost adjustment to be added to energy services charge. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
E.General Conditions.
1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule R-1 is Option A—Seasonal Flat Rate. A customer may choose to receive energy under either option A or B; however, when a customer requests a change of energy rate option, that customer may not change to another energy rate option before twelve months have elapsed.
F.Special Provisions.
1.Electric Utility Assistance Program.
a.Electric Utility Assistance Program (Basic Benefit). Any customer taking service under this schedule shall be eligible for a monthly credit against their electricity bills equal to the fixed charge rate components (customer charge and grid access charge), if the gross annual income per calendar year of the household in which such customer resides does not exceed the greater of: (i) the income level that qualifies for rental assistance under the city's low income rental assistance program; or, (ii) the income eligibility criteria established by the California Public Utilities Commission ("CPUC") Low-Income Oversight Board for rate assistance programs. The department shall periodically certify that the customer is eligible for the basic benefit.
b.Electric Utility Assistance Program (Pasadena Cares). Any customer eligible for the basic benefit shall also be eligible for a credit equal to the public benefit charge provided the customer is either: a) sixty-two years of age or older; or b) meets the criteria of disability as established by the Social Security Administration's Supplemental Income Program for the Aged, Blind and Disabled under Title XVI of the Social Security Act, as amended. The department shall periodically certify that the customer is eligible for the Pasadena Cares benefit.
c.Electric Utility Assistance Program (Medical). Any customer taking service under this schedule with doctor- prescribed life support equipment requiring electric utility service from the department in order to operate shall be eligible for the Basic Benefit regardless of income. To qualify, a customer must submit satisfactory proof to the department that a full-time occupant of the customer's premises requires a life support device.
A qualifying life support device may be any one of the following or such other equipment as the department may deem eligible: aerosol tents, apnea monitors, compressors or concentrators, electrostatic or ultrasonic nebulizers, electric nerve stimulators, hemodialysis machines, kidney dialysis machines, intermittent positive pressure breathing machines, iron lungs, pressure pads, pressure pumps, respirators, or suction machines.
2.Time Periods. Time periods are defined as follows:
a.Summer months are defined as June through September. Winter months are defined as October through May.
b.On-peak hours: 3:00 p.m. to 8:00 p.m.
Off-peak hours: 8:00 p.m. to 3:00 p.m.
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13.04.045 Residential multi-family service. (Schedule R-2) The raterms and conditions of services hereunder shall be as provided by Schedule R-2, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE R-2
Residential Multi-Family Service
A. A.Applicability. Applies to separately metered multi-family dwellings, including properties permitted as "live- work" space when used for residential purposes, and to individual family dwellings in multi-family dwellings.
Multi-family dwellings are apartments, condominiums or town houses with at least four meters at the same physical location. The character of service furnished includes single phase 120/240-volt or 120/208-volt, and 3-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service. Motors with more than 150 amps locked motor are not served under this schedule.
B. Character of Service Furnished. Single phase 120/240-volt or 120/208-volt, and 3 phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service.
C. Conditions of Use. Motors with more than 150 amps locked rotor are not served under this schedule.
B. D.Rates. Customers Customer shall pay the sum of the following charges (1) customer charge, the(2) distribution charge, the (3) grid access charge, (4) energy services charge, (5) transmission services charge, and (6) public benefit charge. The minimum monthly charge shall be equal to the sum of (1) the customer charge and (2) the grid access charge.
C. Customers taking service under Schedule R-2 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. the energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule R-2 shall pay a customer charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$8.96
Effective July 2019:
Grid Access Charge Per Meter Per Month
$4.50
2. Distribution Charge. Customers taking service under Schedule R-2 shall pay a distribution charge based on kWh used during the billing month as follows:
Effective July 2017:
Usage $ per kWh
First 350 kWh per month $0.01889
Next 400 kWh per month $0.14673
All additional kWh per month $0.10706
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B. 3.Transmission Services Charge. Customers taking service under Schedule R-2 shall pay a transmission services charge for each kWh delivered to the in accordance with Section 13.04.170.
C. 4.Energy Services Charge. Customers taking service under Schedule R-2 shall have two energy rate options to choose from for their energy services.
D. 4.1. Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07073
Winter $0.06147
E.
F. 4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.14750
Summer Off-Peak $0.04750
Winter On-Peak $0.11150
Winter Off-Peak $0.05100
This option is subject to meter availability. The customer shall be responsible for the cost of installing the metering equipment required for this service.
4.3 Power Cost Adjustment: Power cost adjustment to be added to energy services charge. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
E.General Conditions.
1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule R-2 is Option A—Seasonal Flat Rate. A customer may choose to receive energy under either option A or B; however when a customer requests a change of energy rate option that customer may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
1. 13.04.046 Electric Utility Assistance Program. utility assistance program (EUAP) a.
The programs hereunder are applicable to customers taking service under the Residential Single-Family Service (Schedule R-1) or Residential Multi-Family Service (Schedule R-2) in addition to the provisions set forth for each program:
A. Electric Utility Assistance Program (-Basic Benefit).. Any customer taking service under this schedule shall be eligible for a monthly credit against their electricity bills equal to the fixed charge rate components (customer charge and grid access charge), if the gross annual income per calendar year of the household in which such customer resides does not exceed the greater of: (i) the: (i) income level that qualifies for rental assistance under the cCity's low income rental assistance program; or, (ii) the income eligibility criteria established by the California Public Utilities Commission ("CPUC") Low-Income Oversight Board for rate assistance programs. The dDepartment shall periodically certify that the customer is eligible for the basic benefit.
B. b.Electric Utility Assistance Program (- Pasadena Cares).. Any customer eligible for the basic benefit shall also be eligible for a credit equal to the public benefit charge provided the customer is either: a) sixty-two years of age or older; or b) meets the criteria of disability as established by the Social Security Administration's Supplemental Income Program for the Aged, Blind and Disabled under Title XVI of the Social Security Act, as 129
amended. The dDepartment shall periodically certify that the customer is eligible for the Pasadena Cares benefit.
C. c.Electric Utility Assistance Program (- Medical).. Any customer taking service under this schedule with doctor- prescribed life support equipment requiring electric utility service from the department in orderDepartment to operate shall be eligible for the Basic Benefit regardless of income. To qualify, a customer must submit satisfactory proof to the dDepartment that a full-time occupant of the customer's premises requires a life support device. A qualifying life support device may be any one of the following or such other equipment as the dDepartment may deem eligible: aerosol tents, apnea monitors, compressors or concentrators, electrostatic or ultrasonic nebulizers, electric nerve stimulators, hemodialysis machines, kidney dialysis machines, intermittent positive pressure breathing machines, iron lungs, pressure pads, pressure pumps, respirators, or suction machines.
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b.On-peak hours: 3:00 p.m. to 8:00 p.m.
Off-peak hours: 8:00 p.m. to 3:00 p.m.
13.04.050 Small commercial and industrial service. (Schedule S-1) The raterms and conditions of services hereunder shall be as provided by Schedule S-1, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE S-1
Small Commercial and Industrial Service
A. Applicability. Applies to single-phase and 3-phase general service, including lighting and incidental small power, through a single meter. Applies to service below 30 kW demand.
B. Character of Service Furnished. Single-phase 120/240 or 120/208 volt, and 3-phase, 120/208, 240, 480, or 277/480 volt, 60-cycle alternating current service.
C. Conditions of Use. Single-phase motors 1/2 HP and larger shall be connected at 240 volts or 208 volts.
Motors 5 HP and larger shall be connected 3 phase. Motor-connected loads in excess of 49 HP are not served under this schedule for new service after April 1, 1969.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule S-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Customer Charge: Per Meter Per Month
$9.42
Effective July 2019:
Grid Access Charge: Per Meter Per Month
$17.00
2. Distribution Charge. Customers taking service under Schedule S-1 shall pay a distribution charge during the billing month as follows:
130
Effective July 2017:
All kWh per month $0.06423
3. Transmission Services Charge. Customers taking service under Schedule S-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule S-1 shall have two energy rate options:
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.06901
Winter $0.06030
4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10463
Summer Off-Peak $0.05706
Winter On-Peak $0.06431
Winter Off-Peak $0.05611
This option is subject to meter availability. The customer shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
4.3 Power Cost Adjustments: Customers taking service under Schedule S-1 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge and the grid access charge under Schedule S-1.
E. General Condition.
1. Selection of Energy Rate Option. The default energy rate option for customers under Schedule S- 1 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate option may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
A. 1.Customers connected to 120/208 volt service whose sole usage of electricity is for residential purposes as defined by the PWP, shall be billed on the residential rate schedule.
A. Applicability. Applies to single-phase and three-phase general service, including lighting and incidental small power, through a single meter. Applies to service below 30 kW demand. The character of service furnished may be single-phase 120/240 or 120/208 volt, and three-phase, 120/208, 240, 480, or 277/480 volt, 60-cycle alternating current service. Customers connected to 120/208 volt service whose sole usage of electricity is for residential purposes as defined by the PWP, shall be billed on the residential rate schedule. Single-phase motors 1/2 hp and larger shall be connected at 240 volts or 208 volts. Motors 5 hp and larger shall be connected 3-phase. Motor-connected loads more than 49 hp are not served under this schedule. 2. Time Periods. Time periods are defined as follows:
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B. a.Summer months are defined as June through September. Winter months are defined as October through May.
C. b.Summer On-peak hours: 12:00 noon to 8:00 p.m.
D. Summer Off-peak hours: 8:00 p.m. to 12:00 noon
E. Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
F. Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
G. c.Weekend and holiday hours are all off-peak.
A. d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
B. Customer shall pay the sum of the following charges (1) customer charge for either (a) single-phase service or (b) three-pha se service, (2) distribution charge, (3) grid access charge, (4) energy services charge, (5) transmission services charge, and (6) public benefit charge. The minimum monthly charge shall be equal to (1) the sum of the customer charge and (2) the grid access charge.
C. Customers taking service under Schedule S-1 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. 132
13.04.060 Medium commercial and industrial service—Secondary.secondary (Schedule M-2) The raterms and conditions of services hereunder shall be as provided by Schedule M-1, as follows2, as found in the Electric Utility Rate Resolution:
SCHEDULE M-1
Medium Commercial and Industrial
Service—Secondary
A. A.Applicability. Applies to 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 17 kV.
B. Character of Service Furnished. 3 phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service.
C. Conditions of Use. Motors of 50 HP or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule M-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Per Meter Per Month
$23.40
Effective July 2019:
Grid Access Charge Per Meter Per Month
$250.00
2. Distribution Charge. Customers taking service under Schedule M-1 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of demand $16.09 per kW
3.Transmission Services Charge. Customers taking service under Schedule M-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4.Energy Services Charge. Customers taking service under Schedule M-1 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07338
Winter $0.06213
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4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10218
Summer Off-Peak $0.06063
Winter On-Peak $0.06578
Winter Off-Peak $0.05785
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 174 kV. The character of service furnished shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Motors of 50 hp or more shall be served as determined by PWP. Billing demand shall not be less than 30 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
A. Customers taking service under Schedule M-2 for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
C.
D. Power Factor Penalty and Discount.
1. Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
3. New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
H. This option is subject to meter availability. Customers shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
I. 4.3 Power Cost Adjustment: Customers taking service under Schedule M-1 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173. 134
J. 5.Minimum monthly charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule M-1.
K. E.General Condition.
L. 1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule M-1 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate optionmay not change to another energy rate option before twelve months have elapsed.
M. F.Special Provision.
N. 1.Determination of Billing Demand. "Billing Demand" shall not be less than 30 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15- minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval.
O. 2.Time Periods. Time periods are defined as follows:
P. a.Summer months are defined as June through September. Winter months are defined as October through May.
Q. b.Summer On-peak hours: 12:00 noon to 8:00 p.m.
R. Summer Off-peak hours: 8:00 p.m. to 12:00 noon
S. Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
T. Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
U. c.Weekend and holiday hours are all off-peak.
V. d.Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
W. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
2. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power actor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent. 135
4. Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b.Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non-holiday weekdays that were not subject to curtailment.
13.04.064 Medium Commercial and Industrial Service—Primary.
The rates and conditions of services hereunder shall be as provided by Schedule M-2, as follows:
SCHEDULE M-2
Medium Commercial and Industrial
Service—Primary
A. Applicability. Applies to 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 17 kV.
B. Character of Service Furnished. 3 phase, 60 cycle alternating current service at normal primary or sub- transmission voltages.
C. Conditions of Use. Motors of 50 HP or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule M-2 shall pay a customer charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$29.75
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Effective July 2019:
Grid Access Charge Per Meter Per Month
$250.00
2. Distribution Charge. Customers taking service under Schedule M-2 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$11.49 per kW
3. Transmission Services Charge. Customers taking service under Schedule M-2 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule M-2 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07154
Winter $0.06121
4.2 Option B—Time-of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10128
Summer Off-Peak $0.05970
Winter On-Peak $0.06481
Winter Off-Peak $0.05713
This option is subject to meter availability. The customer shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
4.3 Power Cost Adjustment: Customers taking service under Schedule M-2 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule M-2.
E. General Condition.
1. Selection of Energy Rate Option. The default energy rate option for customers under Schedule M- 2 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate option may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
1. Determination of Billing Demand. "Billing demand" shall not be less than 30 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the 137
current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval.
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
A. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
4. Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
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a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b. Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non- holiday weekdays that were not subject to curtailment.
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13.04.067 Large064 Medium commercial and industrial service—Secondary.primary (Schedule M-1)
The raterms and conditions of services hereunder shall be as provided by Schedule L-1, as follows:
SCHEDULE LM-1
Large Commercial and Industrial
Service—Secondary, as found in the Electric Rate Utility Resolution:
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-3 phase general service, including power and lighting, measured with demand meter.
Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 174 kV. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 17 kV.
B. Character of Service Furnished. 3 phase 240, 480, 120/208 or 277/480 voltThe character of service furnished shall be three-phase, 60 cycle alternating current service.
A. C.Conditions of Use. at normal primary or sub-transmission voltages. Motors of 50 HPhp or more shall be served as determined by PWP. Billing demand shall not be less than 30 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
Customers taking service under Schedule M-1 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to sum of the customer charge, the distribution charge, and the grid access charge.
D. Rates. Customers Customer shall pay the sum of the following charges (1) customer charge, grid access charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and energy services(6) public benefit charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule LM-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$47.91
Effective July 2019:
Grid Access Charge Per Meter Per Month
$1,500.00
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2. Distribution Charge. Customers taking service under Schedule L-1 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$18.76 per kW
3. Tra
nsmission Services Charge. Customers taking service under Schedule L-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule L-1 shall payhave two energy services charge as follows:
4.1 Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10394
Summer Off-Peak $0.05843
Winter On-Peak $0.06579
Winter Off-Peak $0.05659
4 .2 Power Cost Adjustment: Customers taking service under Schedule L-1 shall pay a PCA, as provided in Section 13.04.173. Raterate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to for the energy services charge, the customer charge, distribution charge, and seasonal flat rate option or the grid access charge under Schedule L-1.
E. Special Provisions.
B. 1.Determination of Billing Demand. "Billing demand" shall not be less than 300 KW. "Billing demand" meansTime-of-Use rate option. A customer may choose to receive energy under either option. Upon the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand metersadoption of Interval Read Capable Meters for billing, all customers will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand isautomatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to sum of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. the customer charge, the distribution charge, and the grid access charge.
2. Time Periods. Time periods are defined as follows:
a. S ummer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
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d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
C. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10nearest one-tenth of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10nearest one-tenth of one percent.
13.04.067 0 Large commercial and industritutional service—Primary.secondary (Schedule L-2) The raterms and conditions of services hereunder shall be as provided by Schedule L-2, as follows: found in the Electric Rate Utility Resolution:
SCHEDULE L-2
Large Commercial and Industrial
Service—Primary
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 174 kV. 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 17 kV.
B. Character of Service Furnished. 3 phaseThe character of service furnished shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service at normal primary or sub- transmission voltages.
C. Conditions of Use.. Motors of 50 HPhp or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule L-2 shall pay a customer charge and a grid access charge during the billing month as follows:
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Effective July 2017:
Customer Charge Per Meter Per Month
$53.90
Effective July 2019:
Grid Access Charge Per Meter Per Month
$1,500.00
2. Distribution Charge. Customers taking service under Schedule L-2 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$11.89 per kW
3. Transmission Services Charge. Customers taking service under Schedule L-2 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule L-2 shall pay an energy services charge as follows:
4.1 Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.09852
Summer Off-Peak $0.05580
Winter On-Peak $0.06617
Winter Off-Peak $0.05629
4.2 Power Cost Adjustment: Customers taking service under Schedule L-2 shall pay a PCA, as provided in Section 13.04.173. Rate Options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule L-2.
E. Special Provisions.
A. 1.Determination of Billing Demand. "Billing demand" shall not be less than 300 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest monthly demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. kW
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
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Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
B. 3.Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
B.C. Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent.
The discount shall be computed to the nearest
1 / 10nearest one-tenth of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better.
A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent.
The discount shall be computed to the nearest
1 / 10nearest one-tenth of one percent.
. 4.Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b.Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for 144
curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non-holiday weekdays that were not subject to curtailment. 7046 § 7, 2006: Ord. 6901 § 8, 2002) (Ord.
13.04.069 Large commercial and institutional service—primary (Schedule L-1) The terms and conditions of services hereunder shall be provided by Schedule L-1, as found in the Electric Utility Rate Resolution.
A. Applicability. Applies to 3-phase general service, including power and lighting, measured with demand meter.
Applies to service for a customer at 300 kW demand or greater for one month out of the previous 12 months.
Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 174 kV. The character of service furnished shall be 3-phase, 60 cycle alternating current service at normal primary or sub-transmission voltages. Motors of 50 hp or more shall be served as determined by PWP. Billing demand shall not be less than 300 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
C. Power Factor Penalty and Discount.
1. Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
3. New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
13.04.070 Extra-large commercial and institutional service—primary (Schedule L-3) The terms and conditions of services hereunder shall be provided by Schedule L-3, as found in the Electric Utility Rate Resolution.
A. Applicability. Applies to customers with one or more dedicated circuit(s), including power and lighting, and aggregate demand of 10MW measured with demand meter. Applies to customers that meet or exceed 10 MW aggregate demand or greater in one month of the prior 12-month period. 145
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) transmission services charge, and (5) public benefit charge. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge under Schedule L-3, and the grid access charge. The customer shall also pay the energy services charge if an alternative rate for energy services is not established through an approved long-term contract pursuant to section 13.04.075.
C. Power Factor Penalty and Discount.
1. If a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
13.04.071 Special load management and conservation service.
A.Subject to the conditions set forth in this section,The special load management and conservation service rate is an optional temporary rate that PWP may enter into temporary special rate agreements and/or rate schedules with qualifying customers in order to: encourage experimentation in load management and conservation programs within customer premises and allow evaluation of load management's effect on the power system; evaluate how best to accommodate the load impacts of new technologies on the power system; experiment with electricity rates and the timing of customer payments for time-of-useTOU meters and other interconnection facilities in order to incentivize customers to shift their electric usage from on-peak to off-peak hours when system costs are lower; and/or reduce the power system's aggregate on-peak electricity demand.
BA. PWP shall publish the temporary rate schedules listing the effective date, customer qualification requirements, and all relevant terms.
CB. Customer shall make application to PWP to take service under any rates schedule offered under this section.
All applications meeting the published requirements shall be accepted in the order of receipt by PWP, subject to the limitations in subsection (E) of this section.
DC. Said temporary special rate agreements and/or rate schedules may be cancelled by PWP, at any time, on notice to the customer, but in no event shall be in effect for a period exceeding thirty-six (36) months.
ED. The energy sales under this section shall be limited to three percent (3%) of the total system energy sales in megawatt-hours, as reported in PWP's most recent annual report. Each customer group shall be allocated a percentage of the energy sales based on the customer group's contribution to the total system energy sales.
FE. Each participating customer shall be limited to ten percent (10%) of the energy sales within its customer group.
13.04.073 Economic development074 Electric vehicle charging rates. (Schedules EV-1, EV-2, and EV-3, and City-owned retail charging stations) The ratesElectric Vehicle (EV) rate is an optional rate designed to encourage EV adoption and support clean transportation. The terms and conditions of services hereunder shall be as provided by Schedule ED, as follows:
Schedule ED
Economic Development Rates for Medium and Large Commercial and Industrial Customers 146
A. s chedules EV-1, EV-2, and EV-3, and CityCity-Owned Retail Charging Stations as found in the Electric UtilityApplicability.
1.The Economic Development Rate is available to new medium and large commercial and industrial customers that:Resolution.
i. Have a 2012 North American Industry Classification System ("NAICS") code in one of the following categories: Construction (23), Manufacturing (31-33), Information (51), Scientific, Technical, and Professional Services (54), or restaurants (722511 or 722110); ii. Must upgrade the existing building and/or the electrical service interconnection thereto; and A. iii.Are adding a minimum of 50Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge.
A. Electric vehicle charging below 30 kW of projected electrical(Schedule EV-1)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and having a maximum demand of less than 30 k W.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge..
3. Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section
13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.
1. B. 2.For existing mediumElectric vehicle charging at or above 30 kW and large commercialless than 300 kW (Schedule EV-2)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and industrial customers, the projected incremental having a maximum demand must be a minimum of 50kWof greater than or equal to 30 kW and less than 300 kW.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution. and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge. or 10% of existing
C. Electric vehicle charging at or above 300 kW (Schedule EV-3)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and having a maximum demand, whichever is greater of greater than or equal to 300 kW.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution.and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge..
DE. City-owned retail charging stations
1. Applicability. Applies to retail customers charging EVs at City-owned stations and shall pay in accordance with the Electric Utility Rate Resolution.
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1.2. Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section
13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section 13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.
3. Customer shall make application to PWP to take service under this schedule. Such application shall indicate whether customer elects to take service under Section 13.04.073(C) (three year rate discount) or Section 13.04.073(D).
4. The City's Economic Development Manager will evaluate the applications to determine whether they meet the proposed business use criteria and the PWP General Manager shall determine whether the customer meets the electrical requirements and qualifies to take service under this Schedule ED.
B. Agreement. Customers shall execute an economic development rate agreement as specified by PWP prior to the effective date of any discount.
C. Option 1 Rate Discount.
1. Except as provided herein, all rates charged will be in accordance with customer's otherwise applicable rate schedule as set forth in the applicable sections of this chapter.
2. The total of the unbundled electric service charges for the distribution, energy, and transmission service charges under the customer's otherwise applicable rate schedule on customer's electric bill associated with the new or incremental load shall be reduced by 20% in the first contract year, 10% in the second contract year; and, 5% in the third and final contract year.
3. For existing customers, the discount will be prorated to reflect only the incremental load that qualifies for the Economic Development Rate.
4. Customer shall compensate PWP for the full cost of electric service connection fees in accordance with Section X of Regulation 21 to qualify for the Rate Discount. Customer must remit 100% of the total estimated cost in advance of PWP performing the work.
D. Option 2 Discounted Interconnection Fees. In lieu of the Rate Discount provided in section C, customer may choose to receive a discount on labor and materials on work performed by PWP to install a new or upgraded electric service connection in accordance with Section X of Regulation 21. The maximum discount for each customer would be $200 per kilowatt of new or incremental load or $100,000, whichever is less. Customer must remit the balance of the total estimated cost in advance of PWP performing the work.
E. Special Provisions.
1. Customer shall comply with all applicable PWP rules and regulations, including without limitation, Regulation 21.
2. Customer must meet Economic Development Rate Qualifying Criteria as determined by the City's Economic Development Manager.
3. Discounts are limited to a maximum of $100,000 per customer over the term of the agreement.
4. The Economic Development Rate will be offered to eligible customers on a first-come first-served basis for three years (from the rate effective date) or until cumulative estimated discounts reach $1,000,000, whichever occurs first.
13.04.080 Standby service. (Schedule SBY)
The raterms and conditions of services hereunder shall be as provided by Schedule S, as follows:SBY, as found in the Electric Utility Rate Resolution.
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A. Applicability. Applicable to customers who in part or in whole have their own generating equipment and who rely on the PWP grid in case of an on-site outage. Standby service shall be furnished solely to the individual contracting customer. Applies to medium and large commercial customers. Character of service shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Other voltages and types of service may be approved by the Department for certain specific installations.
B. Customer shall sign a contract for this service, which contract shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer's generating equipment.
C. Service connections shall be made so that at no time will the customer's generating equipment be connected to or operated in parallel with PWP's system. Switching devices used for service connections shall be approved by PWP.
D. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and (3) the reservation charge.
A. SCHEDULE S
B. Standby Service
C. A.Applicability. Applicable to customers who in part or in whole have their own generating equipment and who contract for standby service from the department.rely on the PWP grid in case of an on-site outage.
Standby service shall be furnished solely to the individual contracting customer in a single enterprise, located entirely on a single, contiguous premise.
D. B.. Applies to medium and large commercial customers. Character of Service. 3service shall be three- phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Other voltages and types of service may be approved by the dDepartment for certain specific installations.
E. C.Rate.
F. Effective July 15, 2012:
Per Meter Per Month
All kW of standby capacity $10.87 per kW
2. Energy Charge Energy shall be billed in accordance with the rate schedule which would otherwise apply if
the customer had no generating equipment.
3. Minimum Monthly Charge The demand charge or $201.40, whichever is greater.
4.Application Charge: For each application for new service, or customer originated account change, to be added to the first bill: $5.00.
D.Special Conditions.
1.Contract Required. Customer shall sign a contract for this service, which contract shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer's generating equipment.
2.Service Connections. B. Service connections shall be made so that at no time will the customer's generating equipment be connected to or operated in parallel with PWP's system. Switching devices used for service connections shall be approved by PWP.
C.Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and (3) the reservation charge.
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13.04.085 Unmetered rates—Nnon-demand. below 30 kW (Schedule CE-1) The raterms and conditions of services hereunder shall be as provided by Schedule CE-1—Non, non- demand, as follows:found in the Electric Utility Rate Resolution.
SCHEDULE CE 1
Non-Demand
A. Applicability. Applies to any unmetered telecommunications devices and other equipment with less than 30 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the City.
B. Monthly energy consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
C. Customer shall pay the sum of the following charges (1) customer charge for either (a) single-phase service or (b) three-phase service. (2) distribution charge, (3) grid access charge, (4) energy services charge based on the monthly energy consumption, (5) transmission services charge, and (6) public benefit charge.
D. Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
E. Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
F. Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
G. From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide City personnel with access to customer's equipment and provide assistance as necessary to complete the audit.
A. A.Applicability. Applies to any unmetered telecommunications devices and other equipment with less than 30 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the cCity.
B. B.Monthly Energy Consumptionenergy consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
C. Rates. Customer shall pay the sum of the following charges:
(1. C) c ustomer charge per connection per month:
Singlefor either (a) single-phase service: $14.16
Three or (b) three-phase service: $19.07
. (2. D ) distribution charge for all kWh per month:
$0.04475 per kWh
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, (3. Transmission Services Charge. Customer shall pay a) grid access charge, (4) energy services charge based on the monthly energy consumption, (5) transmission services charge in accordance with Section 13.04.170 for each kWh delivered.
4. Energy Services Charge. Customer shall pay an energy service charge as follows:
Seasonal Flat Rate:
Season Energy Service Charge per kWh
Summer $0.06901
Winter $0.06030
a.Power Cost Adjustment. Customer shall pay a power cost adjustment in accordance with Section
13.04.173.
5.Public Benefit Charge. Customer shall pay a, and (6) public benefit charge in accordance with Section
13.04.230 for each kWh delivered. .
D. General Conditions.
C. 1.Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
D. 2.Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
1. 3.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
E. 4.From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide cCity personnel with access to customer's equipment and provide assistance as necessary to complete the audit.
13.04.087 Unmetered rates—Demand.demand at or above 30 kW (Schedule CE-2) The raterms and conditions of services hereunder shall be as provided by Schedule CE 2—Demand, as follows:
SCHEDULE CE -2, demand, as found in the Electric Utility Rate Resolution.
Demand
A. A.Applicability. Applies to any unmetered telecommunications devices and other equipment with 30 kW demand or greater, but less than 300 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the cCity.
B. B.Billing Determinants.
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2.1. 1.Monthly Energy Consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
3.2. 2.Monthly Billing Demand. PWP shall determine the monthly billing demand based on the maximum demand (kW) of the telecommunications devices and other equipment as set forth in the manufacturer's specifications.
C. Rates. Customer shall pay the sum of the following charges:
(1. Customer Charge Per Connection Per Month:
Customer) customer charge: $60.22
for either (a) single-phase service or (b) three-phase service. (2.Distribution Charge. The) distribution rate for customer shall be as follows:
All kilowatts of demand: $10.87 per kW
4.3. charge, (3.Transmission Services Charge. Customer shall pay a) grid access charge, (4) energy services charge based on monthly energy consumption, and (5) transmission services charge in accordance with Section 13.04.170 for each kWh delivered. .
4. Energy Services Charge. Customer shall pay an energy service charge as follows:
Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07338
Winter $0.06213
a. Power Cost Adjustment. Customers shall pay a power cost adjustment in accordance with Section 13.04.173.
5. Public Benefit Charge. Customer shall pay a public benefit charge in accordance with Section
13.04.230 for each kWh delivered.
D. General Conditions.
5.4. 1.Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
6.5. 2.Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
F. 3.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
6. 4.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
7. From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide cCity personnel 152
with access to customer's equipment and provide assistance as necessary to complete the audit within seven calendar days of written request.
13.04.090 Street lighting and traffic signal service. (Schedule SL) The raterms and conditions of services hereunder shall be as provided by Schedule SL, as follows:found in the Electric Utility Rate Resolution.
SCHEDULE SL
Street Lighting and Traffic Signals
A. A.Applicability. Applies to outdoor street, highway and area lights and traffic signals, whether publicly or privately owned, where the poles, electrolier standards and lighting equipment are owned by the customer.
For such lights as are burned from 30 minutes after sunset to 30 minutes before sunrise, 4140 hours of service per year will be used for cost calculation purpose.
B. B.Rate. Unmetered street lighting and signs not included in the flat rate section will be billed under the metered rate section using the hours of service per year set forth in subsection A. Unmetered load, including without limitation, traffic signals, street lighting, signs with extended hours of operation, bus shelters, and irrigation controllers will be billed under the metered rate section by extrapolating usage from a sample test metering period. All services covered under this section, whether billed under the flat rate or metered rate section shall also be subject to the transmission services charge and power adjustment chargebilled in accordance with Sections 13.04.170 and 13.04.173. the Electric Utility Rate Resolution.
Effective July 15, 2012:
1. Flat Rate—Lamp Size Monthly Charge
Per Lamp ($)
Incandescent
1,000 lumens $0.94
1,500 lumens 1.11
2,500 lumens 1.95
4,000 lumens 3.14
6,000 lumens 4.47
10,000 lumens 6.79
67 watts 0.86
69 watts 0.88
103 watts 1.30
150 watts 1.89
202 watts 2.54
303 watts 3.80
Mercury Vapor
3,500 lumens 1.61
7,000 lumens 2.64
11,000 lumens 3.66
20,000 lumens 5.80
35,000 lumens 9.81
54,000 lumens 13.87
Fluorescent
213 watts 2.68
248 watts 3.14
High Pressure Sodium
35 watts 0.51
50 watts 0.72
70 watts 1.28
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100 watts 1.76
150 watts 2.43
200 watts 3.09
250 watts 3.94
310 watts 4.81
400 watts 5.98
4—60 watts unit bus stop 4.82
2—40 watts unit bus stop 4.82
Metal Halide 3.99
2. Metered Distribution Rate.
a. For metered street lighting, all energy will be billed at $0.03923 per kWh. b. For metered traffic signals and signs, all energy will be billed at $0.05807 per kWh.
3. Unmetered Distribution Rate.
a. For unmetered traffic signals and signs, all energy will be billed at $0.05807 per kWh.
4. Transmission Services Charge. Customers taking service under Schedule SL shall pay a transmission services charge for each kWh delivered to in accordance with Section 13.04.170.
5. Energy Services Charge. Customers taking service under Schedule SL shall pay energy services charge of $0.065 for each kWh delivered.
6. Power Cost Adjustment. Customers taking service under Schedule SL shall pay a PCA, as provided in Section 13.04.173.
13.04.100 Service regulations and charges.
A. The general manager of the water and power departmentDepartment shall, from time to time, approve service regulations and procedures relating to conditions of service, application, administration and interpretation of rates, or to any other provision of this chapter; provided, however, that any proposed new or revised charges or fees for reconnections and for various special services not otherwise provided for in this chapter shall be effective upon adoption thereof by resolution of the city councilCity Council. No later than 30 days prior to the effective date of any amendments to such regulations, the proposed amendments shall be posted on PWP's website and the city councilCity Council shall be notified in writing of such proposed amendments.
B. On failure to comply with the service regulations of the dDepartment, or to pay charges, or to comply with penalties imposed for such failure as herein provided, electric service may be turned off until the regulations, charges, or said penalties are complied with or payment is made of the amount due.
13.04.110 Meter and service installation.
All meters and services shall be installed and located in accordance with specifications and drawings entitled "Electricdetailed in the Electrical Service Requirements, Regulation No. 21." Regulations set forth by PWP. In the event that meter and service connections are not so installed, the dDepartment will delay making service connections to such premises until the service requirements are satisfied. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. 154
All meters and services shall be installed and located in accordance with specifications and drawings detailed in the Electrical Service Requirements Regulations set forth by PWP. In the event that meter and service connections are not so installed, the Department will delay making service connections to such premises until the service requirements are satisfied. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. Advanced Meters with Interval Read Capability will be the standard of installation, customers wishing to opt out are subject to fees as stated in the Utility Rate Resolution.
Advanced Meters with Interval Read Capability will be the standard of installation, customers wishing to opt out are subject to fees as stated in the Utility Rate Resolution.
13.04.120 Inspections.
A. Entry on Premises. Department employees may enter private premises to make inspections or examinations of wires, fixtures or attachments, to read meters, or to determine if there has been unlawful tampering with department equipment, devices or seals, or unlawful installation of devices to evade department metering of energy. Department employees whose duty it is to enter upon private premises will be provided with a badge or other identification. Such identification shall be shown to customer at the time of entry on customer's premises.
B. Interference with Authorized Employees. The general manager may discontinue service of electrical energy to any premises after written notice to the customer of his intent to do so, for the following causes:
1. The customer has refused admittance to an authorized employee, at a reasonable hour, in the performance of his duty; or
2. The customer, by his personal conduct, or by maintaining a dangerous condition or vicious animal upon the premises, has hindered or interfered with an authorized employee in the performance of his duty.
The general manager shall serve such notice by mailing one copy to the customer at his last known address, and one copy to the premises, if a different address. The general manager need not reconnect the service until the customer has given satisfactory assurance to the general manager that an authorized employee will not be interfered with or hindered, or refused admittance, in the performance of his duty.
C. Access to electric meters at the customers facilities shall be provided at all times. If access to the customers meter is prohibited by a locking device on a gate, door or other access entries, customers shall provide PWP with a key to allow access by meter readers or other authorized personnel for the purpose of inspecting and/or maintaining and/or reading the meter. PWP is authorized to install at the customer's facility a lock box accessible only to PWP authorized personnel for the purpose of securing the key on site to gain ready access to the customer's electric meter.
D. PWP may inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
13.04.125 Private underground electric vaults.
A. On reasonable notice, typically within five business days, the dDepartment may enter upon private property to inspect, repair or replace any private underground electrical vault. It shall be the duty of the owner of a private underground vault to: (i) make the vault freely accessible to department employeesDepartment employees; (ii) maintain the vault in good repair free from water or other unsafe conditions; and (iii) comply with all state and local regulations applicable to underground electrical vaults. Any vault which fails to meet these requirements is hereby deemed a nuisance per se.
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B. In event the condition of a private underground vault does not meet the requirements set forth in subsection A of this section, the dDepartment may proceed with code enforcement proceedings pursuant to Chapters
1.24, 1.26 or 1.30 of the Pasadena Municipal Code. The dDepartment may also, in its discretion, remediate the condition of any private underground vault. Prior to such remediation, the dDepartment shall notify the vault owner of the problems to correct and the time for correcting them. If the problems are not timely corrected, the dDepartment shall notify the vault owner of the dDepartment's proposed solutions to the problems and the department's cost to complete them. The vault owner shall have the right to contest the dDepartment's proposed action by filing an administrative appeal with the general manager of the dDepartment not later than ten days from the date set forth on the dDepartment's notice. In event an appeal is not timely taken, the dDepartment's proposed action shall be the final administrative decision and no resort to the courts may be taken therefrom due to failure to exhaust remedies.
C. All costs of remediating the condition of a private electrical vault shall be the responsibility of the vault owner.
Such costs shall be billed to the vault owner according to the normal billing procedures and requirements applicable to department customers. In event the vault owner does not timely pay in full, the dDepartment may exercise any remedies available to it under this code or other law, including shut-off of electrical service to the premises served by the private underground vault. Costs incurred by the dDepartment in remediating the condition of a private underground vault shall also be recoverable in any proceeding brought pursuant to Chapters 1.24, 1.26 or 1.30 of the Pasadena Municipal Code.
13.04.130 City not liable for damages relating to delivery failures.
The cCity is not liable for any damage to persons or property caused in any manner by the use or application of electric current, nor is it liable for any damage caused by its failure to deliver current, proper voltage or frequency, all or part of 3three-phase current, or electrical energy for any length of time.
13.04.140 Financial responsibility—Delinquency penalty.
A. Customer Liability. The customer is responsible for and shall pay the cCity for all electrical energy delivered to the premises as registered on the cCity meter. The meter bill is due and payable when rendered, and is delinquent 3021 days after the date rendered. If delinquent bills for any electrical service are not paid upon presentation, such service may be discontinued without further notice. In addition, there shall be assessed a penalty assessment for delinquent bills pursuant to Section 1.08.080. The amount of such penalty shall be as set forth on the general fee schedule.
B. Responsibility for Schedule. It is the responsibility of the customer to determine that he is being served under the proper schedule. In the event the customer feels he is not being so served, he shall file with the dDepartment a written statement, stating the reasons therefor. The dDepartment shall then promptly make an investigation and shall inform the customer in writing of its conclusions, and shall adjust the rate or not, accordingly. Department is not liable for excess charges to customer prior to the time customer files the written statement.
C. Deposits. The general manager of the dDepartment may require a deposit in reasonable amount to guarantee payment for electrical energy to be used subsequent to date of demand for such deposit. If any customer fails to make such deposit after demand therefor, electrical service may be discontinued until the deposit required has been made.
D. Reconnection Charge. If electrical service is disconnected for nonpayment of bills, nonpayment of required deposit, by customer request or because of interference with authorized employees of departmentPWP, the appropriate reconnection and special service charges, in addition to all previously accrued charges, shall be made prior to reconnection of service.
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13.04.150 Rate schedule changes.
A customer qualifying for a particular rate schedule will not be transferred to another rate schedule because of temporary or seasonal conditions for the purpose of reducing the minimum or energy charges. Unless there is a major change in the customer's type of load, a particular rate will continue in effect for at least 12 months. except upon the adoption of Interval Read Capable Meters for billing, at which time customer may be automatically enrolled in the Time-of-Use rates. If a major change in type of load occurs in less than 12 months, the dDepartment may charge and collect $3.00 for each meter affected.
13.04.160 Meter readings combined.
The municipal light and power departmentThe Department will not ordinarily combine meter readings for billing purposes. However, in the event a consumer has brought out all of his electric leads to a central and convenient location and more than one meter of a given class is deemed necessary by the dDepartment, the dDepartment may combine the readings of such meters for billing purposes.
13.04.170 Transmission services charge.
A. The transmission services charge (TSC) is designed to capture the transmission revenue requirement (TRR) and net cost savings from joining participating transmission owner (PTO) with California Independent System Operator (CAISO) as defined in subsection (C)(4) of this section and shall be based on actual data obtained from the cCity's accounting system, forecast data obtained from the annual operational planbudget approved by the city councilCity Council, and updated forecast data prepared monthly by PWP.
B. PWP shall calculate the TSC on a quarterlyan as needed basis, and the revised value for this charge shall remain in effect for no less than three months.
C. For purposes of this section, the following definitions apply:
"Full service customers" means customers who choose PWP as their energy supplier.
1. "Net cost savings from being a participating transmission owner with California Independent System Operator (NCS PTO CAISO)") means all PTO revenues received from CAISO, including, but not limited to, PTO TRR, net firm transmission right (FTR) revenues, and high voltage wheeling revenues less all expenses paid to CAISO including, but not limited to, transmission access charges (TAC) and grid- management charges. NCS PTO CAISO shall be subject to an adjustment by CAISO transmission revenue balancing adjustment account.
E. "System energy sales" means the estimated total energy sales delivered to all customers.
2. "Transmission revenue requirement" means is the sum of all costs related to the high-voltage transmission of energy, including, but not limited to, all transmission contracts, wheeling fees, pertinent labor and operating costs, associated general fund transfer, operating margin, debt service, and ISOIndependent System Operator access fees, less the sum of all wholesale revenues received in connection with the sale of any transmission entitlements.
D. The transmission services charge shall be calculated quarterly as follows:
1. Commencing July 1, 2002, a separate transmission services charge fund (TSCF)TSC account shall be maintained for balancing costs and revenues associated with high-voltage transmission and related services. Any transmission access charge fund (TACF)TAC over collection or under collection existing on July 1, 2002 shall be depositedmaintained in the TSCFTSC account balance.
2. The TSCF account balance shall be calculated as the sum of actual revenues from the TSC less the actual TRR plus NCS PTO CAISO.
3. The transmission services charge shall be calculated based on the forecasts for the following twelve months for TRR, NCS PTO CAISO, system energy sales, and the TSCF balance as follows:
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[TRR Forecast - NCS PTO CAISO Forecast - TSCF Balance]
[System Energy Sales Forecast]
4. The result of the formulaTSC shall be calculated and rounded to the nearest mill per kilowatt-hour. This shall be the transmission service charge to be implemented.
5. The transmission services charge for customers served under Schedules M-2 and L-2 or forwhose service are metered and delivered at 17kV 4 kV or higher shall be reduced by $ 0.00019 per kWh.
13.04.173 Power cost adjustment. (PCA)
A. A Power Cost Adjustment (PCA) shall be added to the energy services charge set forth in the service schedules of this chapterElectric Utility Rate Resolution. Each customer shall pay the applicable energy services charge plus a PCA for each kWh delivered to the customer.
B. T
he PCA shall be based on actual data obtained from the cCity's accounting system, forecast data obtained from the annual operational planbudget approved by the City Council, and updated forecast data prepared as frequently as monthly by PWP.
C. PWP shall recalculate the PCA each monthas frequently as monthly, and the resulting values for these charges shall be automatically implemented on the first day of the following month.
D. For purposes of this section, the following definitions apply:
1. 1."Energy Costs" meanscosts" is the sum of all costs related to the procurement and generation of energy for delivery to Full ServiceRetail Customers, including, but not limited to, Power Production Costs and Purchased Power Costs, operating margin, debt service and the general fund transfer associated with these costs.
2. 2."Energy Cost Forecast" means cost forecast" is the forecast of projected Energy Costsenergy costs for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
3. 3."Energy Services Charge Revenue Forecast" meansservices charge revenue forecast" is the forecast of projected Energy Services Charge Revenue energy services charge revenue for the twelve months immediately following the last actual billing period. The energy services charge set forth in the schedules reflects the energy cost forecast as of July 1, 2002, based on the approved rate restructuring plan approved by the City Council adjusted to each customer group's load profile, and shall remain in effect until modified by Ordinance.
4. 4."Energy revenue credit" is a percentage of the Wholesale Net Incomewholesale net income used to reduce the Energy Charge. The Energy Revenue Credit shall be appliedenergy charge. The energy revenue credit is 75% of the wholesale net income, when the Wholesale Net Income is greater than zero and shall be determined at least quarterly based on the actual accounting data as follows: (i) 75% of the Wholesale Net Income shall be applied as a credit; (ii) additional amounts may be authorized by Council Resolution.
5. 5."Energy revenue forecast" meansis the forecast of projected Energy Revenue Creditsenergy revenue credits for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
6. 6."Fuel costs" means the sum of the cost of fuel gas consumed, the cost of fuel oil consumed, and the cost of procuring, scheduling, testing and in-plant handling of that fuel gas and fuel oil. Fuel oil includes both residual fuel oil and distillate fuel oil.
7. "Full service customers" shall mean customers who choose PWP as their energy supplier. 158
7. 8."Full service energy"Retail Energy sales forecast" meansis the forecast of projected energy sales (in kilowatt-hours) to Full Service Customers for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
8. 9."Power production costs" meansis the sum of all costs for the generation of electric energy at facilities owned and operated by PWP, including, but not limited to, Fuel Costs, labor, operating and maintenance expenses, materials, and emissions credits.
10. "Purchased power costs" meansis the cost of energy and ancillary services, including, but not limited to, capacity and energy charges from third parties and all non-transmission charges charged by the California Independent System Operator (ISO).
11. "System energy sales" means the estimated total energy sales delivered to all customers.
12. "Wholesale net income" means the sum of revenues realized from wholesale energy and ancillary service sales, less the associated production cost and purchased power cost attributable to the wholesale sales.
[E—G.Reserved.]
H. The PCA shall be added to the energy service charge set forth in the service schedules, and shall be calculated monthly as follows:
1. Commencing July 1, 2002, a separate Energy Services Charge Fund (ESCF)energy services account balance shall be maintained for balancing costs, revenues, and credits associated with energy delivered to Full Service Customers. Any Energy Charge Fund over collection or under collection existing on July 1, 2002 shall be deposited in the ESCF balance.retail customers.
2. The ESCF account balance shall be calculated as the sum of actual revenues from the Energy Services Charge, the Energy Revenue Credit, and any other credits authorized by the City Council, less the actual Energy Costs inched.
3. Reserved.
4. The Energy Services Chargeenergy services charge shall be calculated based on the Energy Cost Forecast, Energy Revenue Credit Forecast, Full Service Energy Sales Forecast, and the ESCFenergy cost forecast, energy revenue credit forecast, retail service energy sales forecast, and the energy services charge account balance as follows:
[Energy Cost Forecast - Energy Revenue Credit Forecast - Fund Balance] [Full Service Energy Sales Forecast]
5[energy cost forecast - energy revenue credit forecast – energy services charge account balance] [retail energy sales forecast]
3. The PCA shall be calculated based on the twelve month forecast of Energy Services Revenue, Energy Cost, Energy Revenue Credit, Full Service Energy Sales, ESCFenergy services revenue, energy cost, energy revenue credit, retail energy sales, energy services charge account balance and Fund Reserve Targetaccount reserve levels as follows:
[Energy Cost Forecast - Energy Revenue Credit Forecast - Fund Balance - Energy Services Revenue Forecast + Reserve Target]
[Full Service Energy Sales Forecast]
6[energy cost forecast - energy revenue credit forecast – energy services charge account balance - energy services revenue forecast + reserve levels] [retail energy sales forecast]
4. The result of the formula shall be rounded to the nearest millone thousandth per kilowatt-hour. This shall be the PCA to be implemented.
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13.04.178 Self-generation service. (Schedule SG)
Schedule SG
Self-Generation Service
A.Availability. Available and mandatoryTo encourage the development of local renewable energy generation by customer-generators, self-generation service shall be as provided by Schedule SG as follows and as found in the Electric Utility Rate Resolution.
A. Applicability.
1. Applies to customers with self-generation or cogeneration not less than one megawatt capacity and billing demand not less than 300 kW.
2. Customers shall sign an interconnection and metering agreement with PWP.
3. This schedule will be applied to each meter at point of delivery or receipt, and in no event will meter readings be combined.B.Rates.
B. Self-generation service.
1. Rates for this service shall be the same as for the scheduletime-of-use rates 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 (M-l).
2. In except, (1) in each month, billing demand will be the greater of the maximum fifteen15 minute kW of the absolute net power that theelectricity delivered to customer received from or injected into the PWP power system during the current month or preceding eleven11 months.
3. In and (2) in each month, the billing determinant for the Transmission Services Chargetransmission 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 determinants2. Customer 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 energya credit. a. The in an amount equal to the net electricity delivered to PWP multiplied by the applicable energy credit periods shall be one month for customers on seasonal flat rates and TOU periods for customers on TOU ratesservices charge.
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.
c. 3. Billing.
160
a. Customers shall receive a monthly or bi-monthly bill from PWP. Customers shall pay the outstanding balance, if any, owed to PWP.
b. Credits shall be given to the customer in the form of offsets to charges on the customer's bill.future electric bills. If, in any month, a customer's electric credits (including any credit carry-forwards from previous months exceed that customer's charges,) the net credit will carry forward to the customer's bill for the following twelve months. Credits shall expire upon termination of electric service.
64. The customer shall be responsible to reimburse PWP for any and all upgrades to PWP's power system which are necessary due to the customer's generation, including, without limitation, metering equipment.
C. Conditions:
1. The above service is subject to PWP rules and regulations.
2. This schedule will be applied to each meter at point of delivery or receipt, and in no event will meter readings be combined.
3. Customers shall sign an interconnection agreement with PWP.
4. Customers shall comply with Regulation 23.
13.04.179 Green power service.
(Schedule GP)
Green Power Service
A. Applicability. The charges set forth in this schedule apply to those customers who choose green power service.
By subscribing to green power service customers will accelerate the procurement and development of renewable energy resources by paying a green power premium which PWP will then apply to green power procurement on behalf of such customers. Customers choosing this service shall either select a 100% Green power service option or nominate the amount of green service in blocks of 100 kWh per month. All other rates and charges for electric services apply to these customers as specified in their otherwise applicable schedule. "Green power" as used in this section shall mean energy procured from an "Eligible renewable energy resource" as defined in California Public Utility Code Section 399.12(e) to serve customers that have selected Green power service.
B. Green Power Premium. The Green Power Premium shall be $0.018 per kWh of metered electricity use for customers choosing 100% Green power service, or, $1.80 per month for each 100 kWh block of green power nomination.
C. For customers enrolling after March 1, 2026, the Green Power Premium shall be established in the Electric Utility Rate Resolution as of the enrollment date. the value of portfolio content category one (PCC1) renewable energy credits (RECs) based on recent actual transactions by Pasadena Water and Power ($/MWh) C. Use of Green Power. Consistent with PWP's Renewable Portfolio Standard Procurement Plan and Enforcement Program, as may be amended from time to time, PWP shall account for energy procured on behalf of Green power service customers separately from that procured for non-Green power service customers, and shall not utilize the renewable attributes associated with Green power procurement for compliance purposes.
D. The Green Power Premium shall not be included as gross income for purposes of calculating the light and power fund transfer under Sections 1407 and 1408 of the Charter. 161
13.04.180 Theft of energy.
A. In applying for service the customer agrees that the department may install and maintain equipment on the customer's premises for the proper metering of energy and distribution of current to prevent the theft thereof. Any customer who tampers with department's equipment to avoid payment of the rates herein prescribed, or to reconnect service that has been disconnected by department, is liable to punishment therefor pursuant to law. Upon discovery of such tampering, the general manager may cause the service to be disconnected and remove all equipment installed by the department forthwith. If the premises is vacant or the equipment installed is no longer needed, such equipment may be removed at any time upon order of the general manager of the department.
B. Any person or agency apprehended using electricity without permission from a power line, electrical service, or other system connection will be charged for each occurrence a minimum of $300.00, or such other charge as established by resolution Electric Utility Rate Resolution of the city councilCity Council, plus the cost of electricity estimated to have been used. Investigation costs may be added thereto at the option of the general manager.
13.04.190 Apparatus causing interference.
The department may disconnect any service on its lines to which is connected any device or apparatus causing a distortion of the wave form of the voltage or current supplied, or generating or causing high frequency electrical radiation or other electrical disturbance, which interferes with radio or television broadcast reception or with other forms of communication, or with the operation of any of department's protection or control facilities.
The owner of such device or apparatus shall have a reasonable time within which to repair, modify or adjust, or to agree to pay department's costs of devices, apparatus and installation, to prevent interference.
13.04.200 Billing procedure.
A. The rates established apply basically to monthly periods. The meter reading dates shall be determined by the dDepartment and bills will be rendered monthly or bimonthly at the option of the department. Bimonthly bills will be computed by doubling the monthly energy block and the monthly customer or minimum charge. When service to a customer is initiated or terminated between regular meter reading dates for a particular premises, the bill will be prorated on a basis established by the general manager.
B. Notwithstanding anything in this chapter to the contrary, billing may be made and charges collected for service furnished hereunder to any customer at such times as the department considers to be in the best interests of the department and the customer so billed. Charges billed for a period of more than 1one month are made as though monthly meter readings had been taken and had shown equal use of service each month within the period and charges had been billed monthly thereon.
13.04.210 Gaseous lighting units
All vapor or discharge tube type lighting units, such as neon, argon and fluorescent lighting, shall include power factor corrective equipment so that the overall power factor shall not be less than 90%. All installations of corrective equipment rated at 250 volt-amperes or more shall be approved by the Department.
13.04.220 Added load.
Customers shall notify and secure approval of dDepartment before adding any power load of 3 HPhp or appliance load of 3 KW or greater to an existing service. 162
13.04.230 Public benefit charge.
A. Pursuant to the requirements of Section 385 of the Public Utilities Code of the state of California, there is established a nonbypassable, usage based public benefit charge on local distribution service for each kilowatt- hour delivered to the customer.
B. The public benefit charge shall be based on data obtained from the city's accounting system and updated forecast data prepared quarterly by the department.
C. The departmentDepartment shall recalculate the public benefit charge quarterlyannually and the resulting value for this charge shall be automatically implemented on the first day of the following month.
DC. For the purpose of calculating the public benefit charge, the following definitions shall apply:
1. "Public benefit cost" means expenditures pursuant to subsections (G)(1) through (G)(4), inclusive.
2. "Public benefit cost forecast" means the forecast of public benefit cost for the twelve months immediately following the last billing period.
3. "Public benefit fund balance" means the sum of all prior revenues from the public benefit charge, less the sum of all prior public benefit cost and committed public benefit cost.
4. "Full service Retail energy sales forecast" means the forecast of projected energy sales (in kilowatt-hours) to all electric customers taking service under this chapter for the twelve months immediately following the last billing period.
ED. The public benefit charge shall be calculated based on the public benefit cost forecast, the public benefit fund balance, and the fullretail service energy sales forecast as follows: the public benefit cost forecast minus the public benefit fund balance, which sum shall be divided by the fullretail service energy sales forecast. The result shall be rounded to the nearest mill per kilowatt-hour.
FE. In no event shall the public benefit charge be less than $0.00271 per kilowatt-hour.
GF. Moneys collected through the public benefit charge will be used exclusively to fund investments in any or all of the following:
1. Cost-effective demand -side management services to promote energy efficiency, energy conservation, and electric demand reduction;
2. New investment or incentives to promote the installation and use of renewable energy resources and technologies consistent with existing statutes and regulations which promote those resources and technologies;
3. Research, development and demonstration programs for the public interest to advance science or technology which is not adequately provided by competitive and regulated markets; and
4. Services provided for low-income electricity customer, including but not limited to, targeted energy efficiency service and rate discounts.
HG. This public benefit charge shall not be subject to any taxes or surcharges imposed pursuant to the Pasadena Municipal Code.
IH. This public benefit charge shall not be included as gross income for purposes of calculating the light and power fund transfer under Sections 1407 andSection 1408 of the Charter.
163
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
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 Ch $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 ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
1 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
13.04.060 Grid Access Charge per meter per month N/A $250.00000 $250.00000 $250.00000
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 Ch 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 Ch $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 Ch 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 C $7,175.91000 N/A N/A N/A 2 of 6
165
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 C 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 C 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 C $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 C 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
3 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 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
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 5 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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
169
MUNICIPAL COD MUNICIPAL 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 Char $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 E: REVISED DRAFT RATE SCHEDULE ALTERNATIVE 1 1 of 5
170
MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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 Char 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 Char $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 Char 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 Cha $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 Cha N/A $7,695.00000 $8,440.000002 of 5 171
MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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 Cha 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 Cha $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 Cha 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 5 172
MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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
13.04.178 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
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
13.04.179 Green power service (GP)
13.04.179 Green power premium per kWh $0.01800
4 of 5
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MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT RATE SCHEDULE ALTERNATIVE 1
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
174
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
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 Ch $756.10000 N/A N/A N/A
13.04.060 Medium commerical service - secondary (M-2)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2 1 of 6
175
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 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
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 Ch 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 Ch $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 Ch 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 C $7,175.91000 N/A N/A N/A 2 of 6
176
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED 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 C 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 C 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 C $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 C 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
3 of 6
177
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2
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 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
178
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED 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 5 of 6
179
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2
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
180
PASADENA WATER AND POWER
MEMORANDUM
The fol
lowing document is section 2 of the Electric Rate Study, this next phase of the study evaluates how current electric rates align with the actual costs of providing service to each customer class. This next step within the rate-making process comes after determining the system revenue requirement and then establishes a revenue requirement for each customer class, which is determined based on the specific costs to serve that class.
The CO
S analysis reveals that 77% of PWP’s costs are fixed, driven by infrastructure, power supply contracts, and customer service operations. Only 23% are variable, such as fuel and purchased power. This fixed-cost structure underscores the importance of rate design that ensures stable revenue recovery.
Key f
indings include:
• Residential customers currently under-recover by approximately 39%, while Medium Commercial c
ustomers slightly over-recover.
• The cost
to connect to the PWP system, regardless of energy usage, is $125/month for R
esidential customers, reflecting the infrastructure and service readiness
costs.
The COS framework also introduces a new Electric Vehicle (EV) customer class, laying the groundwork for future rate structures tailored to EV charging needs.
This analysis will inform the next phase of the study: rate design, which aims to align rates with actual service costs, promote equity, and support long-term financial sustainability.
Attachment B: Cost of Service Report
181
Ec
onomics | Strategy | Stakeholders | Sustainability PWP Electric Rate Study Final Report Section 3
ELECTRIC COST-OF-SERVICE
After determining the system revenue requirement, a revenue requirement for each customer class was determined based on the specific costs to serve each class. Customer class revenues are compared to class revenue requirements to evaluate the current rate ’s abilities to fully recover costs. NewGen analyzed the cost to serve each customer class based on the revenue requirement developed in Section 2.
Once completed, the CO S results indicate the degree to which existing rates recover the costs to serve customers. The COS results are then used to design new electric rates.
The COS analyses relied on the following key supporting data and analysis:
Revenue requirements and revenues based on current rates. Total system and customer class demand and energy requirements. Actual and assumed customer service characteristics.
Information obtained from customer accounts and records.
Cost-of-Service Process
NewGen performed an analysis of the cost to serve each customer class based on the revenue requirement developed in Section 2. There are three steps in developing the COS for each customer class, as illustrated in steps 2–4 in Figure 3-1 below.
Figur
e 3-1. Cost-of-Service Process
Step 1 is the development of the revenue requirement as explained in Section 2.
Step 2 is the functional unbundling of the revenue requirement. Functional unbundling provides detailed descriptions of the utility’s revenue requirement by core utility function. Accounting 182
information is provided by PWP budget accounts. If an item has been adjusted, the amount of the adjustment is identified with an associated supporting calculation. Once the detailed revenue requirement has been established, the amount is assigned to the production, transmission, distribution, and customer functions. Assignments are made either through direct assignments or other allocation methodology. The results of the Component A analyses for each function of the revenue requirement are expressed on a functional basis.
Step 3 is the classification and sub- functional unbundling of the revenue requirement. Sub - functionalizing the production, transmission, distribution, and customer functions developed in Step 2 provides additional detail and accuracy to PWP’s costs. Additionally, costs are classified as demand related, energy related, customer related, or a direct assignment. Like functionalizing, sub- functionalization is accomplished either through direct assignments or other allocation methodology. Specific allocation factors are found at the bottom of each sub -function worksheet.
Step 3 analyses result in PWP’s revenue requirement expressed on a sub -functional basis for each cost classification (e.g., Production Demand or Production Energy Costs).
Step 4 is the allocation of the classified and sub-functionalized costs to the customer classes. Using the information developed in Step 3, the sub -functionalized and classified revenue requirement is allocated to each of the rate classes using various customer class allocation methodologies. These allocation methodologies or allocators are developed in alignment with the cost classification. For example, production demand costs are allocated utilizing the customer’s contributions to system demand such as four-coincident peak (4CP) or the highest four months of PWP system peaks.
Once completed, the COS results indicate the degree to which existing rates recover the costs to serve customers. These results are then used in designing new electric rates.
Functionalization
PWP’s electric rates have been unbundled into four functions: production, transmission, distribution, and customer. Descriptions of each utility function are below.
Production Function
The production function consists of costs associated with operating and maintaining electric generation facilities and making capital investments, as necessary. This function also includes purchased power, fuel, and power labor costs.
Transmission Function
The transmission function consists of costs associated with transmitting power from generation plants or the CAISO markets to PWP’s local load. These costs include market transmission costs, operating and maintaining transmission lines and related infrastructure , and making capital investments, as necessary.
Distribution Function
The distribution function consists of costs associated with operating and maintaining the localized distribution portion of the electric grid and making capital investments, as necessary. The distribution facilities deliver power to the retail customers after it has been transmitted. This includes primary and secondary voltage distribution lines, distribution poles, underground lines, customer service connections, meters, and lighting -related assets. PWP has 1,660 miles of overhead and underground lines.
183
Customer Function
The customer function consists of costs associated with operating and maintaining the customer related facilities to meet customer support needs. This includes, but is not limited to, customer service, and billing and collection. PWP services approximately 68,000 electric customers, and over 59,000 are in the Residential Service class.
Functionalized Revenue Requirement
The revenue requirement was “unbundled” into the four functional areas of the system: production, transmission, distribution, and customer. The results of the functional unbundling are summarized in Table 3-1.
Table 3-1
Functionalized Revenue Requirement
Function Revenue $/kWh(1) % of Total Requirement
Production $127,296,677 $0.1224 49%
Transmission $12,494,313 $0.0120 5%
Distribution $105,410,519 $0.1013 41%
Customer $14,355,356 $0.0138 6%
Total $259,556,865 $0.2496 100%
(1) Based on Test Year energy sales of 1,040,083,319 kWh.
The production function, including P WP’s operating expenses and purchased power, represents 49% of the revenue requirement. The distribution function is the second largest cost center, representing 41% of the revenue requirement. The customer function is the third largest cost center, representing 6% of the revenue requirement. The remaining 5 % of the revenue requirement is associated with the transmission function.
Classification
System costs can be classified into four generally accepted rate -making cost classifications:
(i) demand or fixed costs, (ii) energy or variable costs, (iii) customer- related costs, and (iv) directly assignable costs. To provide a reasonable basis for the assignment or allocation of total revenue requirements (costs) to each customer class, costs for each function in the electric system have been analyzed and classified into four categories. P WP’s functional costs were classified on the following basis:
1. Demand Costs – Capacity (fixed- or demand-related) costs are those costs incurred to maintain a utility system in a state of readiness to serve, enabling it to meet the total combined demands of its customers. Capacity costs include the portion of O&M expenses, debt service, capital expenditures, and other costs that are generally fixed and do not vary materially with the quantity of usage, or that cannot be designated specifically as a customer or variable cost.
2. Energy Costs – Energy or variable costs are costs that vary directly with energy usage, including such items as fuel, energy-related purchased power, and a portion of O&M expenses. 184
3. Customer Costs – Customer costs are those costs directly related to the number and type of customers, such as customer accounting, billing, service connections, and meter -related expenses.
4. Direct Assignment Costs – Direct assignment costs are those costs that are readily identifiable and applicable to a customer or customer class (e.g., street lighting).
Once the costs within each function are assigned to each service category, the demand, energy, customer, and direct assignment component of each service is calculated. As seen in Table 3 -2, three major cost categories (demand, energy, and customer) cover most of all functional costs. This breakdown of demand, energy, customer, and direct assignment costs is later applied to each customer class to facilitate the electric system rate design, as provided in Section 4. The classified revenue requirement is shown below in Table 3-2.
Classified Revenue Requirement
In total, 23% of PWP’s total revenue requirement is energy-related or variable costs. The remaining 77% of the revenue requirement is fixed in nature and classified as demand, customer, or directly assigned to particular customer classes. Table 3-2 shows additional details regarding the classified costs within each function and classifies the costs within each.
Table 3-2
Classified Revenue Requirement
Classification Revenue $/kWh(1) % of Total(2) Requirement Production
Demand $80,394,286 $0.0773 31%
Energy $46,902,391 $0.0451 18%
Subtotal $127,296,677 $0.1224 49%
Transmission
Demand $0 $0.0000 0%
Energy $12,494,313 $0.0120 5%
Subtotal $12,494,313 $0.0120 5%
Distribution
Demand $88,989,628 $0.0856 34%
Customer $12,725,008 $0.0122 5%
Other $3,695,883 $0.0036 1%
Subtotal $105,410,519 $0.1013 41%
Customer
Customer $14,355,356 $0.0138 6%
Subtotal $14,355,356 $0.0138 6%
Demand $169,383,914 $0.1629 65%
Energy $59,396,704 $0.0571 23%
Customer $30,776,248 $0.0296 12%
Total Costs $259,556,865 $0.2496 100%
(1) Based on Test Year energy sales of 1,040,083,319 kWh. (2) Percentages may not add to 100% due to rounding. 185
Allocation
Based upon actual and assumed customer service characteristics, NewGen developed various factors for use in allocating the adjusted revenue requirements to individual customer classes.
These allocation factors reflect accepted rate -making principles and were based upon sufficiently distributed embedded cost allocation procedures. The following summary describes the specific allocation factors used in the Study.
Once revenue requirements are classified, they are allocated to the individual customer classes based on customer usage characteristics. For the system and customer classes, we have developed demand -related, energy -related, customer -related, and direct as signment allocation factors as described below.
Demand Allocations
Demand allocation refers to the basis on which capacity -related costs are distributed or assigned (i.e., allocated) among the various customer classes for the purpose of determining the COS for each class. The demand allocation factors that were developed reflect the cost responsibility of the various customer classes with respect to their contribution to demand -related system characteristics (i.e., contribution to monthly peak demand).
For example, monthly coincident peak demand by customer class reflects the customer class’s contribution to the monthly system peak demand. The peak demand is often referred to as the “Coincident Peak” (CP) because it is the amount of total load from all customers collectively at the same time (coincident with each other).
Non-coincident peak (NCP) demand reflects the customer class’s peak demand, whenever that may occur, and does not have to coincide with the overall system peak. The NCP demand allocation method is based on the theory that demand costs are strongly influenced by the highest demand of each customer class, regardless of when that class peak demand occurs. NCP demand allocators are primarily used to allocate distribution-related costs because the design of these facilities is more consistent with the demand of the classes, rather than the demand of the entire system. Coincident and non- coincident demands are typically calculated considering a one, three, four, or twelve - month period.
The data used to calculate CP and NCP were developed utilizing PWP’s billing database and Proxy Advanced Metering Infrastructure (AMI) from a nearby utility with similar usage profiles. AMI meters record energy usage on a 15-minute or hourly basis which can be used to pinpoint each class’s contribution to system or local peaks. These system and local peaks are the key driver for PWP’s costs to deliver electric service. Figure 3 -2 shows the customer class contributions to P WP’s monthly system peak demands, or the CPs.
186
Figur
e 3-2. Monthly PWP System Peak Demands
Production Demand Allocation
As seen in Figure 3 -2, the PWP system has a dramatic peak during the summer months of June through September. This system peak is what PWP must design, construct, and operate their generation and transmission system to serve. However, as PWP must plan and build infrastructure to supply production services for those four peak months, those costs and assets may not be utilized year-round to meet the other eight months of system demands. As such, PWP’s production functionalized costs were sub -functionalized into a base load PWP -owned and peak load costs.
Subsequently, the base load costs which support year-round system peaking needs are allocated to customer classes on a 12 CP method. Similarly, the peak load costs associated with meeting summer peaking demands are allocated to the customer classes using the 4CP method. This is an appropriate cost allocation methodology for the southern California climate and load profile as it captures the class-level contributions to the peak system demand in the summer months but also recognizes some costs and assets are used year-round.
Distribution Demand Allocation
Similarly, distribution costs are designed to meet the maximum demands of the localized system or customers, so 4 non-coincident peak (4 NCP) and the sum of maximum demands (SMD) allocation factors are used. An NCP allocator is typically used to allocate distribution costs as these facilities are sized to meet localized peak demands rather than the system peak demand. The 4 NCP method was used to allocate the distribution system demand -related costs associated with substations, primary lines, and secondar y lines . The SMD was used to allocate demand costs related to distribution transformers near customer service locations. The SMD is reflective of the localized demands customers place on the system at and near the meter. For customer classes that are billed for demand, the SMD represents annual measured demand.
187
Table 3-3 compares the various demand allocators utilized in the Study.
Table 3-3
Demand Allocation Factors
Customer Class 4 CP 4 NCP SMD
Residential 37.65% 43.41% 52.20%
Commercial - Small 13.45% 11.80% 13.77%
Medium - Commercial
Primary and Secondary
Service
21.95% 19.19% 16.10%
Large - Commercial Primary
and Secondary Service 26.71% 24.58% 17.31%
Street Lighting 0.00% 0.93% 0.59%
Traffic Signals 0.24% 0.09% 0.04%
Total 100.00% 100.00% 100.00%
Energy Allocations
Energy allocation factors are the basis for allocating costs or expenses classified as variable or energy related and are assumed to vary directly with kWh sales. Energy -related costs classified as variable include fuel, variable O&M costs, and purchased power. Typically, net energy for load (NEFL), or the energy necessary to supply each customer class, is used to allocate these types of costs to individual customer classes. NEFL is also sometimes called adjusted metered load or energy at generator, as it takes into consideration energy losses that occur on the transmission and distribution systems between the power generation facility and the customer’s meter. For PWP all transmission costs are energy related as a result, NEFL was used as the allocation method. Table 3- 4 lists the energy allocation factors utilized in the Study.
Table 3-4
Energy Allocation Factors
Customer Class Net Energy
for Load
Residential 31.03%
Commercial - Small 13.32%
Medium - Commercial Primary
and Secondary Service 24.87%
Large - Commercial Primary
and Secondary Service 29.76%
Street Lighting 0.90%
Traffic Signals 0.12%
Total 100%
188
Customer Allocations
Customer costs are defined as those costs related to the number of customers and the type of service required. Included in the customer -related costs are the costs associated with meter reading, customer service, sales, billing, collection, and other cust omer-related activities. The customer allocation factors were largely based on the number of customers in each class.
At times in a COS study, certain customer-related costs can be allocated to the various customer classifications based on a weighted customer allocation factor. Weighting reflects that servicing certain types of customers requires more effort and expense than other types of customers. For PWP, weighting factors were not required, nor developed, based on discussions with PWP as there were limited customer service related costs . Public benefits costs were also included in this function; however, they were allocated based on the revenue requirement of each class to reflect the cost causation of the public benefit charge mechanism.
Cost-of-Service Results
The COS process is an industry -accepted framework that assigns costs to customer classes. This process determines the “cost to serve” each customer class within a utility.
Fixed and Variable Costs
Electric utility costs are typically characterized as either fixed or variable; fixed costs are those that do not change with the production of electricity, whereas variable costs are related to the amount of electricity produced and/or purchased. PWP’s
fixed costs are 77 % of the total revenue
requirement. The remaining 23 % of costs are
variable and include fuel, purchased power, and
variable O&M. PWP’s fixed costs are higher than
some industry peers due to the number of power
supply contracts or power purchase agreements
that have fixed components to the contracts or
cost structure. These contracts also provide
PWP physical assets and hedges in the CAISO
market to mitigate market risks to customers.
Fixed Cost to Connect to the PWP System
As stated above, the test year fixed costs are
77% of the total revenue requirement. There is a
cost for each customer to attach to the P WP
system whether or not that customer uses any
energy. As shown in Table 3-5, it costs $125 per month for each Residential customer to be attached to the PWP system, whether they use 0 kWh or 1,000 kWh. The fixed cost per a customer for each class is displayed below.
Figure 3-3. Test Year Fixed and Variable Costs
189
Table 3-5
Fixed Cost Per Customer to Connect to the PWP System
Function Residential Small -
Commercial
Medium -
Commercial
Large -
Commercial
Street
Lighting
Traffic
Signals System
Power Supply $40 $121 $1,946 $16,928 $2,637 $123 $99 Transmission $0 $0 $0 $0 $0 $0 $0
Distribution $56 $118 $1,857 $15,306 $26,782 $33 $109 Customer $29 $36 $199 $903 $29 $29 $38
Total
$/Month/customer $125 $275 $4,002 $33,137 $29,448 $185 $246
The power supply and distribution fixed costs represent the demand-related costs of infrastructure and expenses translated into a monthly cost per customer. The customer- related costs are associated with customer service and customer accounting serving the classes. As seen in the table it costs PWP a minimum of $125 per customer per month to provide service, and that cost does not vary with the amount of energy or kWhs consumed.
Cost-of-Service Results by Class
Table 3-6 summarizes the total cost of service for each customer class. These costs are delineated into the discrete classified costs within each function. Please note the Electric Vehicle (EV) customer class shown in Table 3-6 is a new customer class that does not currently have any customers or billed consumption. Existing services to EV charging stations or locations are provided under an existing applicable commercial class such as Medium or Large Commercial tariff rates. As there are no customers, there are no revenues. The EV cost of service will be used in supporting the tracking of costs for these types of sites and services in addition to the development of new rates and tariffs focused on serving EV charging locations and loads.
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PWP Electric Rate Study Final Report 10
Table 3-6
Cost-of-Service Results by Class
Classification Residential Small - Commercial Medium -
Commercial Large - Commercial Street Lighting Traffic Signals
EV - Electric
Vehicle Total
Production
Demand $28,404,624 $11,009,880 $18,113,051 $22,495,897 $81,736 $289,097 $0 $80,394,286 Energy $14,553,395 $6,247,648 $11,666,870 $13,956,636 $421,047 $56,794 $0 $46,902,391 Subtotal Production $42,958,019 $17,257,528 $29,779,921 $36,452,534 $502,784 $345,891 $0 $127,296,677 Transmission
Demand $0 $0 $0 $0 $0 $0 $0 $0
Energy $3,876,874 $1,664,309 $3,107,934 $3,717,904 $112,163 $15,129 $0 $12,494,313 Subtotal Transmission $3,876,874 $1,664,309 $3,107,934 $3,717,904 $112,163 $15,129 $0 $12,494,313 Distribution
Demand $39,683,928 $10,773,454 $17,283,753 $20,340,010 $830,254 $78,229 $0 $88,989,628 Customer $11,098,069 $1,423,515 $145,370 $20,756 $484 $36,814 $0 $12,725,008 Other $0 $0 $0 $0 $0 $0 $3,695,883 $3,695,883
Subtotal Distribution $50,781,997 $12,196,969 $17,429,123 $20,360,766 $830,738 $115,042 $3,695,883 $105,410,519 Customer
Customer Service $2,309,645 $974,724 $974,724 $974,724 $101 $7,661 $0 $5,241,579 Customer Accounting $5,375,670 $689,521 $704,144 $201,076 $235 $17,832 $0 $6,988,476 Meter Reading $1,796,618 $230,447 $23,533 $3,360 $78 $5,960 $0 $2,059,996 EV - Electric Vehicle $0 $0 $0 $0 $0 $0 $65,305 $65,305 Subtotal Customer $9,481,933 $1,894,691 $1,702,401 $1,179,160 $414 $31,453 $65,305 $14,355,356 Total Costs (Revenue
Requirement) $107,098,823 $33,013,498 $52,019,379 $61,710,363 $1,446,098 $507,516 $3,761,188 $259,556,865 Summarized Total
Demand $68,088,552 $21,783,334 $35,396,804 $42,835,907 $911,990 $367,326 $0 $169,383,914 Energy $18,430,269 $7,911,957 $14,774,804 $17,674,540 $533,210 $71,924 $0 $59,396,704 Customer $20,580,002 $3,318,207 $1,847,772 $1,199,916 $898 $68,266 $3,761,188 $30,776,248 Total $107,098,823 $33,013,498 $52,019,379 $61,710,363 $1,446,098 $507,516 $3,761,188 $259,556,865 191
PWP Electric Rate Study Final Report 11
Cost-of-Service Results Compared to Current Revenue
To evaluate the ability of current rates to adequately recover the COS, NewGen calculated revenues based on Test Year billing data and current rates, then compared the resulting revenues to the COS for each customer class. The results of the comparison are shown in Table 3 -7. This represents a snapshot of the test year revenue requirements which include costs for FY 2025/26 and FY 2026/27 compared to the current rates.
At a system level, current rates and revenues require a one-time 13.9% increase to collect the full COS. Also shown in Table 3-7 is the approximate percentage increase/(decrease) in each customer class's revenues necessary to fully recover the COS for the test year. The percentage increase or decrease shown in the table provides guidance for future rate design without subsidization and with full rate revenue recovery.
Table 3-7
Current Rate Revenues Compared to Cost-of-Service
Class/Service Revenue
Requirement
Estimated Test
Year Revenues
with Current Rates
Projected Over
(Under) Recovery
COS Rate Increase
(Decrease) Needed
(%)
Residential $107,098,823 $76,972,473 ($30,126,350) 39.14% Commercial - Small $33,013,498 $31,068,587 ($1,944,911) 6.26% Medium - Commercial
Primary and
Secondary Service
$52,019,379 $54,463,401 $2,444,022 -4.49%
Large - Commercial
Primary and
Secondary Service
$61,710,363 $62,371,800 $661,436 -1.06%
Street Lighting $1,446,098 $2,721,576 $1,275,478 -46.87% Traffic Signals $507,516 $392,553 ($114,963) 29.29%
EV - Electric Vehicle $3,761,188 $0 ($3,761,188) 0%
Total $259,556,865 $227,990,390 ($31,566,476) 13.85%
(1) EV customer class is not yet in-service or available. Costs are being tracked for the development of future classes and tariffs. As such, no revenues or COS rate changes are identified at this time.
The comparison of the COS results to the current revenues informs the eventual rate design and strategy for FY 2025/26 and beyond. While the COS results represent a one-time rate adjustment to achieve the test year revenue requirement, PWP has multiple options regarding the implementation of rates and the potential to phase-in the rate changes over multiple years. By phasing in rate changes over multiple years, PWP can reduce the potential bill change and increase impacts to customers.
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Section 13.04.010 Short title.
This chapter shall be named and may hereafter be designated as "the light and power rate ordinance."
13.04.020 Definitions.
A. Abbreviations.
1. "K.W.H.," as herein used, indicates and “Apparent power” means "kilowatt hours."
2. "K.W.," as herein used, means "kilowatt," anthe total electrical unit of power.
3. "H.P.," as herein used, means "horsepower," a mechanical unit of power.
A. B."Air conditioning apparatus" is an electrically driven mechanically operated compressed-refrigerant-type cooler of sufficient capacity required to properly cool that portionsupply a load, regardless of how efficiently the enclosed rooms normallypower is used for business purposes. .
B. “Customer charge” is a fixed monthly charge regardless of energy use. It is generally associated with services such as billing, customer service, meter reading, and connection to the grid.
C. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month.
C."Billing demand is determined to the nearest kW.
B.D. “Department," "Pasadena Water and Power" or "PWP," as herein used, means the "municipal water and power department of the cCity of Pasadena." .
D. "Electric water heater" must not exceed the following limitations. The base heating element shall be controlled by a thermostat located near the bottom of the tank and shall not exceed a total rating of 2500 watts or 50 watts per gallon for tanks over 50-gallon capacity. A booster heating element will be allowed in the tank and shall not exceed a total rating of 2500 watts or 50 watts per gallon for tanks over 50-gallon capacity when individually controlled by a separate thermostat set to cut in only when the temperature of the top ⅓ of the tank capacity is 20 degrees Fahrenheit below the temperature setting of the bottom thermostat. Large storage-type tanks are recommended which have heavy insulation.
E. E. “Distribution charge” is a usage-based charge generally associated with the cost of delivering electricity from the substations, including operation and maintenance costs, capital investment and debt service.
F. “Electric Utility Rate Resolution” means a schedule of pricing for all fees, penalties, refunds, reimbursements, and charges of any kind collected by the Department and adopted by City Council.
G. “Energy services charge” (including power cost adjustment) is a usage-based charge generally associated with the solely variable cost of generating the actual amount of electricity consumed, measured in kilowatt-hours.
H. "Greenhouse gas" or "GHG" is a collective term for those gases that reduce the loss of heat from the earth's atmosphere, and thus contribute to global warming and climate change.
I. “Grid access charge” is a fixed monthly charge generally associated with the fixed costs of connecting to and maintaining the electric grid, regardless of their energy consumption.
J. “Holidays” refer to days recognized by the North American Electric Reliability Corporation (NERC) that typically impact electricity demand and pricing. Holidays include New Year’s Day (January 1), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25). These holidays may be updated from time to time based on NERC guidelines.
K. “Horsepower” or "hp," as herein used means a mechanical unit of power.
L. “Interval Read Capable Meter” refers to electric meters that can record and transmit energy usage data at regular, predefined intervals, rather than providing a cumulative total once per billing cycle.
Attachment C: Redline of Chapter 13
193
M. “kilowatt” or "kW" is a unit of power equal to one thousand watts. It measures the rate at which energy is used or produced.
N. "kWh" as herein used, indicates and means "kilowatt hours." A kWh is a standard unit of energy used to measure electricity consumption. It represents the amount of energy used when a device that consumes 1,000 watts (or 1 kilowatt) operates for one hour.“
O. “megawatt” or "MW" is a unit of power equal to one million watts. A MW is a unit of power that measures the rate at which energy is used or produced.
P. "MWh" as herein used, indicates and means "megawatt hours." A MWh is a standard unit of energy used to measure electricity consumption. It represents the amount of energy used when a device that consumes one million watts and operates for one hour.
Q. “Net deficit electricity” means the electricity consumed by a customer-generator, as measured in kWh, exceeds electricity generated by that eligible customer-generator.
R. “Net neutral electricity” means the electricity consumed by a customer-generator, as measured in kWh, equals the electricity generated by that eligible customer-generator.
S. “Net surplus electricity” means the electricity generated by a customer-generator, as measured in kWh, exceeds the amount of electricity consumed by that eligible customer-generator.
T. "Portfolio content category one (PCC1)" means an eligible renewable energy resource interconnected or scheduled into a California balancing authority at the same time of generation pursuant to Sections 399.16(b)(1), 399.16(c)(1) and 399.30(c)(3) of the California Public Utilities Code.
C.U. "Power equipment" means electrical machinery such as motors, welding machines, battery chargers, radio- sending and X-ray equipment will normally be operated on a separate power meter. However, some power equipment, especially smaller size equipment, may be added and operated on the regular lighting meter, provided the starting and stopping or fluctuating load characteristics do not cause objectionable voltage fluctuations in any service rendered by the dDepartment. The use of power equipment on lighting or combination meters must have the approval of the general manager of the dDepartment.
F. Power:
1. Real Power. The work producing part of "apparent power" or rate of supply of energy—usually expressed in kilowatts (kW).
V. 2.“Power Factor“ means the ratio of real power (kilowatts) to apparent power (kilovolt-amperes) for any given load and time (maximum value = 1.0). Power Factor = Real Power/Apparent Power W. “Public benefit charge” is a state-mandated nonbypassable, usage-based public benefit charge to fund assistance programs, energy efficiency and renewable energy projects.
D.X. “Reactive Power. The“ means the portion of "apparent power" which does no work but must be supplied to power equipment, such as motors—usually expressed in kilovars (kvar).
Y. 3.“Real Power Factor. The ratio” means the work producing part of real power (kilowatts) to "apparent power (kilovolt-amperes) for any given load" or rate of supply of energy—usually expressed in kilowatts (kW).
Z. "Renewable energy credit" or "REC" means a certificate of proof that one unit of electricity was generated by an eligible renewable energy resource. RECs are accumulated on a kWh basis and one REC represents the green attributes associated with the generation of one MWh from the electric generation facility.
AA. “Reservation Charge” is the monthly demand charge applied to the customer’s total nameplate capacity (kW) CC.
BB. "Retail customers" means customers who choose PWP as their energy supplier.
CC. "System energy sales" means the estimated total energy sales delivered to all customers. 194
DD. “Time-of-Use” or “TOU” is electricity pricing where the price of electricity varies depending on the time (maximum value = 1.0). of day, day of the week, and season. Electricity is more expensive during peak demand periods.
EE. “Transmission services charge” is a usage-based charge generally associated with the cost of delivering electricity from the generating plants to our sub-stations.
13.04.030 Light and power rate standards.
The rates to be charged and collected for furnishing and delivering electrical energy, and the terms, provisions and conditions respecting such rates, delivery of electrical energy and for service supplied by the municipal light and power department of the city to customers served by the departmentDepartment shall be fixed as set forth in the following sections.
13.04.031 Pricing, pricing periods, and seasons
A. Pricing: The pricing for all fees, penalties, refunds, reimbursements, and charges of any kind collected by the Department pursuant to the provisions of this chapter shall be specified in the Electric Utility Rate Resolution, as amended by the Council from time to time. Whenever applicable throughout this chapter, reference shall be made to the Electric Utility Rate Resolution in lieu of any reference to specific fee amounts.
B. Seasonal Periods: Pricing varies between high and low demand months and the associated costs to provide services during those time periods. Prior to Interval Read Capable Meter Implementation, there are two time- period blocks on-peak and off-peak defined in the Electric Utility Rate Resolution. After Interval Read Capable Meter Implementation, there will be three time- period blocks, on-peak, off-peak and critical peak.
C. Prior to Interval Read Capable Meter implementation: “High Season” means the period of June through September and “Low Season” means the period of October through July.
D. After Interval Read Capable Meter Implementation: “High Season” means the period of July through October and “Low Season” means the period of November through June.
E. Time-of-Use Periods. “Time-of-Use” or “TOU” periods reflect when systems costs are high or low to signal to customers to shift usage to times that are better for the overall electric system and provide pricing for service components which varies by time of day and season of the year. The three time-of-use periods are “on-peak”, “off-peak” and “critical-peak” that vary in their times based on electric system energy costs.
13.04.040 Residential single-family service. (Schedule R-1) The raterms and conditions of services hereunder shall be as provided by Schedule R-1, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE R-1
Residential Single-Family Service
A. A.Applicability. Applies to separately metered single-family dwellings and to individual family accommodations. with single phase 120/240-volt or 120/208-volt, and three-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service. Motors with more than 150 amps locked motor are not served under this schedule.
B. Character of Service Furnished. Single phase 120/240-volt or 120/208-volt, and 3-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service.
C. Conditions of Use. Motors with more than 150 amps locked rotor are not served under this schedule.
D. Customer Rates. Customers shall pay the sum of the following charges (1) customer charge, grid access charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, (5) transmission services charge, and energy services charge as specified below. 195
B. 1.Customer Charge and Grid Access Charge. Customers taking service under Schedule R-(6) public benefit charge. The minimum monthly charge shall be equal to the sum of the (1 shall pay a) customer charge and a(2) the grid access charge during the billing month as follows: .
B.C. Customers taking service under Schedule R-1 shall have two energy rate option for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed.
Effective July 2017:
Customer Charge Per Meter Per Month
$8.96
Effective July 2019:
Grid Access Charge Per Meter Per Month
$4.50
2. Distribution Charge. Customers taking service under Schedule R-1 shall pay a distribution charge based on kWh used during the billing month as follows:
Effective July 2017:
Usage $ per kWh
First 350 kWh per month $0.01889
Next 400 kWh per month $0.14673
All additional kWh per month $0.10706
3. Transmission Services Charge. Customers taking service under Schedule R-1 shall pay a transmission services charge for each kWh delivered to the in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule R-1 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07073
Winter $0.06147
4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.14750
Summer Off-Peak $0.04750
Winter On-Peak $0.11150
Winter Off-Peak $0.05100
This option is subject to meter availability. The customer shall be responsible for the cost of installing the metering equipment required for this service.
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4.3 Power Cost Adjustment: Power cost adjustment to be added to energy services charge. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
E.General Conditions.
1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule R-1 is Option A—Seasonal Flat Rate. A customer may choose to receive energy under either option A or B; however, when a customer requests a change of energy rate option, that customer may not change to another energy rate option before twelve months have elapsed.
F.Special Provisions.
1.Electric Utility Assistance Program.
a.Electric Utility Assistance Program (Basic Benefit). Any customer taking service under this schedule shall be eligible for a monthly credit against their electricity bills equal to the fixed charge rate components (customer charge and grid access charge), if the gross annual income per calendar year of the household in which such customer resides does not exceed the greater of: (i) the income level that qualifies for rental assistance under the city's low income rental assistance program; or, (ii) the income eligibility criteria established by the California Public Utilities Commission ("CPUC") Low-Income Oversight Board for rate assistance programs. The department shall periodically certify that the customer is eligible for the basic benefit.
b.Electric Utility Assistance Program (Pasadena Cares). Any customer eligible for the basic benefit shall also be eligible for a credit equal to the public benefit charge provided the customer is either: a) sixty-two years of age or older; or b) meets the criteria of disability as established by the Social Security Administration's Supplemental Income Program for the Aged, Blind and Disabled under Title XVI of the Social Security Act, as amended. The department shall periodically certify that the customer is eligible for the Pasadena Cares benefit.
c.Electric Utility Assistance Program (Medical). Any customer taking service under this schedule with doctor- prescribed life support equipment requiring electric utility service from the department in order to operate shall be eligible for the Basic Benefit regardless of income. To qualify, a customer must submit satisfactory proof to the department that a full-time occupant of the customer's premises requires a life support device.
A qualifying life support device may be any one of the following or such other equipment as the department may deem eligible: aerosol tents, apnea monitors, compressors or concentrators, electrostatic or ultrasonic nebulizers, electric nerve stimulators, hemodialysis machines, kidney dialysis machines, intermittent positive pressure breathing machines, iron lungs, pressure pads, pressure pumps, respirators, or suction machines.
2.Time Periods. Time periods are defined as follows:
a.Summer months are defined as June through September. Winter months are defined as October through May.
b.On-peak hours: 3:00 p.m. to 8:00 p.m.
Off-peak hours: 8:00 p.m. to 3:00 p.m.
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13.04.045 Residential multi-family service. (Schedule R-2) The raterms and conditions of services hereunder shall be as provided by Schedule R-2, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE R-2
Residential Multi-Family Service
A. A.Applicability. Applies to separately metered multi-family dwellings, including properties permitted as "live- work" space when used for residential purposes, and to individual family dwellings in multi-family dwellings.
Multi-family dwellings are apartments, condominiums or town houses with at least four meters at the same physical location. The character of service furnished includes single phase 120/240-volt or 120/208-volt, and 3-phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service. Motors with more than 150 amps locked motor are not served under this schedule.
B. Character of Service Furnished. Single phase 120/240-volt or 120/208-volt, and 3 phase 120/208 or 240 volt service when used for residential purposes only, 60-cycle alternating current service.
C. Conditions of Use. Motors with more than 150 amps locked rotor are not served under this schedule.
B. D.Rates. Customers Customer shall pay the sum of the following charges (1) customer charge, the(2) distribution charge, the (3) grid access charge, (4) energy services charge, (5) transmission services charge, and (6) public benefit charge. The minimum monthly charge shall be equal to the sum of (1) the customer charge and (2) the grid access charge.
C. Customers taking service under Schedule R-2 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. the energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule R-2 shall pay a customer charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$8.96
Effective July 2019:
Grid Access Charge Per Meter Per Month
$4.50
2. Distribution Charge. Customers taking service under Schedule R-2 shall pay a distribution charge based on kWh used during the billing month as follows:
Effective July 2017:
Usage $ per kWh
First 350 kWh per month $0.01889
Next 400 kWh per month $0.14673
All additional kWh per month $0.10706
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B. 3.Transmission Services Charge. Customers taking service under Schedule R-2 shall pay a transmission services charge for each kWh delivered to the in accordance with Section 13.04.170.
C. 4.Energy Services Charge. Customers taking service under Schedule R-2 shall have two energy rate options to choose from for their energy services.
D. 4.1. Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07073
Winter $0.06147
E.
F. 4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.14750
Summer Off-Peak $0.04750
Winter On-Peak $0.11150
Winter Off-Peak $0.05100
This option is subject to meter availability. The customer shall be responsible for the cost of installing the metering equipment required for this service.
4.3 Power Cost Adjustment: Power cost adjustment to be added to energy services charge. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
E.General Conditions.
1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule R-2 is Option A—Seasonal Flat Rate. A customer may choose to receive energy under either option A or B; however when a customer requests a change of energy rate option that customer may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
1. 13.04.046 Electric Utility Assistance Program. utility assistance program (EUAP) a.
The programs hereunder are applicable to customers taking service under the Residential Single-Family Service (Schedule R-1) or Residential Multi-Family Service (Schedule R-2) in addition to the provisions set forth for each program:
A. Electric Utility Assistance Program (-Basic Benefit).. Any customer taking service under this schedule shall be eligible for a monthly credit against their electricity bills equal to the fixed charge rate components (customer charge and grid access charge), if the gross annual income per calendar year of the household in which such customer resides does not exceed the greater of: (i) the: (i) income level that qualifies for rental assistance under the cCity's low income rental assistance program; or, (ii) the income eligibility criteria established by the California Public Utilities Commission ("CPUC") Low-Income Oversight Board for rate assistance programs. The dDepartment shall periodically certify that the customer is eligible for the basic benefit.
B. b.Electric Utility Assistance Program (- Pasadena Cares).. Any customer eligible for the basic benefit shall also be eligible for a credit equal to the public benefit charge provided the customer is either: a) sixty-two years of age or older; or b) meets the criteria of disability as established by the Social Security Administration's Supplemental Income Program for the Aged, Blind and Disabled under Title XVI of the Social Security Act, as 199
amended. The dDepartment shall periodically certify that the customer is eligible for the Pasadena Cares benefit.
C. c.Electric Utility Assistance Program (- Medical).. Any customer taking service under this schedule with doctor- prescribed life support equipment requiring electric utility service from the department in orderDepartment to operate shall be eligible for the Basic Benefit regardless of income. To qualify, a customer must submit satisfactory proof to the dDepartment that a full-time occupant of the customer's premises requires a life support device. A qualifying life support device may be any one of the following or such other equipment as the dDepartment may deem eligible: aerosol tents, apnea monitors, compressors or concentrators, electrostatic or ultrasonic nebulizers, electric nerve stimulators, hemodialysis machines, kidney dialysis machines, intermittent positive pressure breathing machines, iron lungs, pressure pads, pressure pumps, respirators, or suction machines.
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b.On-peak hours: 3:00 p.m. to 8:00 p.m.
Off-peak hours: 8:00 p.m. to 3:00 p.m.
13.04.050 Small commercial and industrial service. (Schedule S-1) The raterms and conditions of services hereunder shall be as provided by Schedule S-1, as followsfound in the Electric Utility Rate Resolution:
SCHEDULE S-1
Small Commercial and Industrial Service
A. Applicability. Applies to single-phase and 3-phase general service, including lighting and incidental small power, through a single meter. Applies to service below 30 kW demand.
B. Character of Service Furnished. Single-phase 120/240 or 120/208 volt, and 3-phase, 120/208, 240, 480, or 277/480 volt, 60-cycle alternating current service.
C. Conditions of Use. Single-phase motors 1/2 HP and larger shall be connected at 240 volts or 208 volts.
Motors 5 HP and larger shall be connected 3 phase. Motor-connected loads in excess of 49 HP are not served under this schedule for new service after April 1, 1969.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule S-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Customer Charge: Per Meter Per Month
$9.42
Effective July 2019:
Grid Access Charge: Per Meter Per Month
$17.00
2. Distribution Charge. Customers taking service under Schedule S-1 shall pay a distribution charge during the billing month as follows:
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Effective July 2017:
All kWh per month $0.06423
3. Transmission Services Charge. Customers taking service under Schedule S-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule S-1 shall have two energy rate options:
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.06901
Winter $0.06030
4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10463
Summer Off-Peak $0.05706
Winter On-Peak $0.06431
Winter Off-Peak $0.05611
This option is subject to meter availability. The customer shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
4.3 Power Cost Adjustments: Customers taking service under Schedule S-1 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge and the grid access charge under Schedule S-1.
E. General Condition.
1. Selection of Energy Rate Option. The default energy rate option for customers under Schedule S- 1 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate option may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
A. 1.Customers connected to 120/208 volt service whose sole usage of electricity is for residential purposes as defined by the PWP, shall be billed on the residential rate schedule.
A. Applicability. Applies to single-phase and three-phase general service, including lighting and incidental small power, through a single meter. Applies to service below 30 kW demand. The character of service furnished may be single-phase 120/240 or 120/208 volt, and three-phase, 120/208, 240, 480, or 277/480 volt, 60-cycle alternating current service. Customers connected to 120/208 volt service whose sole usage of electricity is for residential purposes as defined by the PWP, shall be billed on the residential rate schedule. Single-phase motors 1/2 hp and larger shall be connected at 240 volts or 208 volts. Motors 5 hp and larger shall be connected 3-phase. Motor-connected loads more than 49 hp are not served under this schedule. 2. Time Periods. Time periods are defined as follows:
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B. a.Summer months are defined as June through September. Winter months are defined as October through May.
C. b.Summer On-peak hours: 12:00 noon to 8:00 p.m.
D. Summer Off-peak hours: 8:00 p.m. to 12:00 noon
E. Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
F. Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
G. c.Weekend and holiday hours are all off-peak.
A. d.Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
B. Customer shall pay the sum of the following charges (1) customer charge for either (a) single-phase service or (b) three-phase service, (2) distribution charge, (3) grid access charge, (4) energy services charge, (5) transmission services charge, and (6) public benefit charge. The minimum monthly charge shall be equal to (1) the sum of the customer charge and (2) the grid access charge.
C. Customers taking service under Schedule S-1 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed.
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13.04.060 Medium commercial and industrial service—Secondary.secondary (Schedule M-2) The raterms and conditions of services hereunder shall be as provided by Schedule M-1, as follows2, as found in the Electric Utility Rate Resolution:
SCHEDULE M-1
Medium Commercial and Industrial
Service—Secondary
A. A.Applicability. Applies to 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 17 kV.
B. Character of Service Furnished. 3 phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service.
C. Conditions of Use. Motors of 50 HP or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule M-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Per Meter Per Month
$23.40
Effective July 2019:
Grid Access Charge Per Meter Per Month
$250.00
2. Distribution Charge. Customers taking service under Schedule M-1 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of demand $16.09 per kW
3.Transmission Services Charge. Customers taking service under Schedule M-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4.Energy Services Charge. Customers taking service under Schedule M-1 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07338
Winter $0.06213
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4.2 Option B—Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10218
Summer Off-Peak $0.06063
Winter On-Peak $0.06578
Winter Off-Peak $0.05785
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 174 kV. The character of service furnished shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Motors of 50 hp or more shall be served as determined by PWP. Billing demand shall not be less than 30 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
A. Customers taking service under Schedule M-2 for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
C.
D. Power Factor Penalty and Discount.
1. Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
3. New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
H. This option is subject to meter availability. Customers shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
I. 4.3 Power Cost Adjustment: Customers taking service under Schedule M-1 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173. 204
J. 5.Minimum monthly charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule M-1.
K. E.General Condition.
L. 1.Selection of Energy Rate Option. The default energy rate option for customers under Schedule M-1 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate optionmay not change to another energy rate option before twelve months have elapsed.
M. F.Special Provision.
N. 1.Determination of Billing Demand. "Billing Demand" shall not be less than 30 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15- minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval.
O. 2.Time Periods. Time periods are defined as follows:
P. a.Summer months are defined as June through September. Winter months are defined as October through May.
Q. b.Summer On-peak hours: 12:00 noon to 8:00 p.m.
R. Summer Off-peak hours: 8:00 p.m. to 12:00 noon
S. Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
T. Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
U. c.Weekend and holiday hours are all off-peak.
V. d.Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
W. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
2. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power actor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent. 205
4. Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b.Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non-holiday weekdays that were not subject to curtailment.
13.04.064 Medium Commercial and Industrial Service—Primary.
The rates and conditions of services hereunder shall be as provided by Schedule M-2, as follows:
SCHEDULE M-2
Medium Commercial and Industrial
Service—Primary
A. Applicability. Applies to 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 17 kV.
B. Character of Service Furnished. 3 phase, 60 cycle alternating current service at normal primary or sub- transmission voltages.
C. Conditions of Use. Motors of 50 HP or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule M-2 shall pay a customer charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$29.75
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Effective July 2019:
Grid Access Charge Per Meter Per Month
$250.00
2. Distribution Charge. Customers taking service under Schedule M-2 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$11.49 per kW
3. Transmission Services Charge. Customers taking service under Schedule M-2 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule M-2 shall have two energy rate options.
4.1 Option A—Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07154
Winter $0.06121
4.2 Option B—Time-of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10128
Summer Off-Peak $0.05970
Winter On-Peak $0.06481
Winter Off-Peak $0.05713
This option is subject to meter availability. The customer shall be responsible for the cost of purchasing and installing the metering equipment required for this service.
4.3 Power Cost Adjustment: Customers taking service under Schedule M-2 shall pay a PCA, as provided in Section 13.04.173. Rate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule M-2.
E. General Condition.
1. Selection of Energy Rate Option. The default energy rate option for customers under Schedule M- 2 is Option A—Seasonal Flat Rate. Customers may choose to receive energy under either option A or B; however, a customer who receives a change of energy rate option may not change to another energy rate option before twelve months have elapsed.
F. Special Provisions.
1. Determination of Billing Demand. "Billing demand" shall not be less than 30 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the 207
current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval.
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
A. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10 of one percent.
4. Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
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a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b. Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non- holiday weekdays that were not subject to curtailment.
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13.04.067 Large064 Medium commercial and industrial service—Secondary.primary (Schedule M-1)
The raterms and conditions of services hereunder shall be as provided by Schedule L-1, as follows:
SCHEDULE LM-1
Large Commercial and Industrial
Service—Secondary, as found in the Electric Rate Utility Resolution:
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 30 kW demand or greater, but less than 300 kW demand. Any customer served under this schedule whose monthly maximum demand has registered less than 30 kW or greater than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule M-3 phase general service, including power and lighting, measured with demand meter.
Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 174 kV. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 17 kV.
B. Character of Service Furnished. 3 phase 240, 480, 120/208 or 277/480 voltThe character of service furnished shall be three-phase, 60 cycle alternating current service.
A. C.Conditions of Use. at normal primary or sub-transmission voltages. Motors of 50 HPhp or more shall be served as determined by PWP. Billing demand shall not be less than 30 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
Customers taking service under Schedule M-1 shall have two energy rate options for the energy services charge, the seasonal flat rate option or the Time-of-Use rate option. A customer may choose to receive energy under either option. Upon the adoption of Interval Read Capable Meters for billing, all customers will be automatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to sum of the customer charge, the distribution charge, and the grid access charge.
D. Rates. Customers Customer shall pay the sum of the following charges (1) customer charge, grid access charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and energy services(6) public benefit charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule LM-1 shall pay a customer charge and a grid access charge during the billing month as follows:
Effective July 2017:
Customer Charge Per Meter Per Month
$47.91
Effective July 2019:
Grid Access Charge Per Meter Per Month
$1,500.00
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2. Distribution Charge. Customers taking service under Schedule L-1 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$18.76 per kW
3. Transmission Services Charge. Customers taking service under Schedule L-1 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule L-1 shall payhave two energy services charge as follows:
4.1 Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.10394
Summer Off-Peak $0.05843
Winter On-Peak $0.06579
Winter Off-Peak $0.05659
4.2 Power Cost Adjustment: Customers taking service under Schedule L-1 shall pay a PCA, as provided in Section 13.04.173. Raterate options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to for the energy services charge, the customer charge, distribution charge, and seasonal flat rate option or the grid access charge under Schedule L-1.
E. Special Provisions.
B. 1.Determination of Billing Demand. "Billing demand" shall not be less than 300 KW. "Billing demand" meansTime-of-Use rate option. A customer may choose to receive energy under either option. Upon the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand metersadoption of Interval Read Capable Meters for billing, all customers will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand isautomatically enrolled in the Time-of-Use rates. Until such time, Time-of-Use rates are subject to meter availability. When a customer requests a change of energy rate option, they may do so in writing and that customer may not change to another energy rate option before twelve months have elapsed. The minimum monthly charge shall be equal to sum of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. the customer charge, the distribution charge, and the grid access charge.
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
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d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
C. 3.Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10nearest one-tenth of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest1 / 10nearest one-tenth of one percent.
13.04.067 0 Large commercial and industritutional service—Primary.secondary (Schedule L-2) The raterms and conditions of services hereunder shall be as provided by Schedule L-2, as follows: found in the Electric Rate Utility Resolution:
SCHEDULE L-2
Large Commercial and Industrial
Service—Primary
A. Applicability. Applies to three-phase general service, including power and lighting, measured with demand meter. Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-2 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages less than 174 kV. 3 phase general service, including power and lighting, measured with demand meter. Applies to service at 300 kW demand or greater. Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 17 kV.
B. Character of Service Furnished. 3 phaseThe character of service furnished shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service at normal primary or sub- transmission voltages.
C. Conditions of Use.. Motors of 50 HPhp or more shall be served as determined by PWP.
D. Rates. Customers shall pay the sum of customer charge, grid access charge, distribution charge, transmission services charge, and energy services charge as specified below.
1. Customer Charge and Grid Access Charge. Customers taking service under Schedule L-2 shall pay a customer charge and a grid access charge during the billing month as follows:
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Effective July 2017:
Customer Charge Per Meter Per Month
$53.90
Effective July 2019:
Grid Access Charge Per Meter Per Month
$1,500.00
2. Distribution Charge. Customers taking service under Schedule L-2 shall pay a distribution charge during the billing month as follows:
Effective July 2017:
All kilowatts of
demand
$11.89 per kW
3. Transmission Services Charge. Customers taking service under Schedule L-2 shall pay a transmission services charge for each kWh delivered in accordance with Section 13.04.170.
4. Energy Services Charge. Customers taking service under Schedule L-2 shall pay an energy services charge as follows:
4.1 Time-Of-Use Rate:
Time-of-Use Energy Services Charge per kWh
Summer On-Peak $0.09852
Summer Off-Peak $0.05580
Winter On-Peak $0.06617
Winter Off-Peak $0.05629
4.2 Power Cost Adjustment: Customers taking service under Schedule L-2 shall pay a PCA, as provided in Section 13.04.173. Rate Options A and B are subject to adjustment as provided in Section 13.04.173.
5. Minimum Monthly Charge: Customers shall pay a minimum charge equal to the customer charge, distribution charge, and the grid access charge under Schedule L-2.
E. Special Provisions.
A. 1.Determination of Billing Demand. "Billing demand" shall not be less than 300 KW. "Billing demand" means the greater of (i) the kilowatts of measured maximum demand occurring during the current month or (ii) the highest monthly demand recorded in the last four months, including the current billing month. Demand is determined to the nearest kW. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. kW
2. Time Periods. Time periods are defined as follows:
a. Summer months are defined as June through September. Winter months are defined as October through May.
b. Summer On-peak hours: 12:00 noon to 8:00 p.m.
Summer Off-peak hours: 8:00 p.m. to 12:00 noon
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Winter On-peak hours: 6:00 a.m. to 10:00 p.m.
Winter Off-peak hours: 10:00 p.m. to 6:00 a.m.
c. Weekend and holiday hours are all off-peak.
d. Holidays are New Year's Day, Martin Luther King Jr. Day, Lincoln's Birthday, Washington's Birthday, Memorial Day, Independence Day, Labor Day, Veteran's Day, Thanksgiving Day, Day after Thanksgiving, and Christmas.
B. 3.Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
B.C. Power Factor Penalty and Discount.
1. a.Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent.
The discount shall be computed to the nearest
1 / 10nearest one-tenth of one percent.
3. b.New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better.
A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent.
The discount shall be computed to the nearest
1 / 10nearest one-tenth of one percent.
. 4.Regulation by PWP. PWP may at any time inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
5. Curtailable Service.
a. Rates: PWP may solicit customer bids for curtailable service. In making such solicitations, PWP shall inform bidders of: i) the time period(s) that would likely be subject to curtailment; and ii) limitations, if any, on PWP's right to curtail service, including limitations on the number of curtailments, the duration of each curtailment, and minimum notice of curtailments. Bidders shall specify the minimum load level to which their service may be curtailed; and the minimum price that they would accept for each kWh curtailed. For hours in which the bidder provides this service to PWP, the bidder shall receive from PWP a billing credit equal to the product of the quantity of customer load actually curtailed and the hourly curtailment price which was bid and accepted by PWP. b.Actual Curtailment Quantities: In each hour that PWP curtails a customer's service, PWP will quantify that hour's actual curtailment quantity by subtracting the customer's metered load in that hour from the customer's "normal load" for that hour. The customer's "normal load" for an hour is defined as the average of the customer's loads for the same hours of the five most recent "comparable days" that have not been subject to curtailments or objectively identifiable abnormal circumstances that have significantly affected customer consumption. "Comparable days" are as follows: for curtailments on Sundays and holidays, recent Sundays and holidays; for 214
curtailments on non-holiday weekdays (Monday through Friday), recent non-holiday weekdays; and for Saturdays, recent Saturdays. Thus, by way of an example, the "normal load" for a Tuesday on the hour ending 3:00 p.m. would be the average of the loads in each of the hours ending 3:00 p.m. on the five most recent non-holiday weekdays that were not subject to curtailment. 7046 § 7, 2006: Ord. 6901 § 8, 2002) (Ord.
13.04.069 Large commercial and institutional service—primary (Schedule L-1) The terms and conditions of services hereunder shall be provided by Schedule L-1, as found in the Electric Utility Rate Resolution.
A. Applicability. Applies to 3-phase general service, including power and lighting, measured with demand meter.
Applies to service for a customer at 300 kW demand or greater for one month out of the previous 12 months.
Any customer served under this schedule whose monthly maximum demand has registered less than 300 kW for twelve consecutive months is no longer eligible for service under this Schedule L-1 and must take service under another applicable rate schedule. This schedule is subject to meter availability. Applies to services metered and delivered at voltages equal to or greater than 174 kV. The character of service furnished shall be 3-phase, 60 cycle alternating current service at normal primary or sub-transmission voltages. Motors of 50 hp or more shall be served as determined by PWP. Billing demand shall not be less than 300 kW.
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) energy services charge, and (5) transmission services charge, and (6) public benefit charge.
The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge.
C. Power Factor Penalty and Discount.
1. Existing Loads: If a customer's load operates at a power factor of less than 75 percent, PWP may require installation of equipment to correct the power factor to 75 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 75 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
3. New Loads: On or after July 1, 2002, if a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
4. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
13.04.070 Extra-large commercial and institutional service—primary (Schedule L-3) The terms and conditions of services hereunder shall be provided by Schedule L-3, as found in the Electric Utility Rate Resolution.
A. Applicability. Applies to customers with one or more dedicated circuit(s), including power and lighting, and aggregate demand of 10MW measured with demand meter. Applies to customers that meet or exceed 10 MW aggregate demand or greater in one month of the prior 12-month period. 215
B. Customer shall pay the sum of the following charges (1) customer charge, (2) distribution charge, (3) grid access charge, (4) transmission services charge, and (5) public benefit charge. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge, and the grid access charge. The minimum monthly charge shall be equal to the sum of the customer charge, the distribution charge under Schedule L-3, and the grid access charge. The customer shall also pay the energy services charge if an alternative rate for energy services is not established through an approved long-term contract pursuant to section 13.04.075.
C. Power Factor Penalty and Discount.
1. If a customer's load operates at a power factor of less than 85 percent, PWP may require installation of equipment to correct the power factor to 85 percent or better. A penalty of one percent of the distribution charge for each percent the average monthly power factor falls below 85 percent shall be added to the distribution charge.
2. A customer having a maximum demand of 50 kW or more shall be allowed a discount on the distribution charge of 0.333 percent for each percent the average monthly power factor exceeds 85 percent. The discount shall not exceed 5 percent. The power factor shall be computed to the nearest one percent. The discount shall be computed to the nearest one-tenth of one percent.
13.04.071 Special load management and conservation service.
A.Subject to the conditions set forth in this section,The special load management and conservation service rate is an optional temporary rate that PWP may enter into temporary special rate agreements and/or rate schedules with qualifying customers in order to: encourage experimentation in load management and conservation programs within customer premises and allow evaluation of load management's effect on the power system; evaluate how best to accommodate the load impacts of new technologies on the power system; experiment with electricity rates and the timing of customer payments for time-of-useTOU meters and other interconnection facilities in order to incentivize customers to shift their electric usage from on-peak to off-peak hours when system costs are lower; and/or reduce the power system's aggregate on-peak electricity demand.
BA. PWP shall publish the temporary rate schedules listing the effective date, customer qualification requirements, and all relevant terms.
CB. Customer shall make application to PWP to take service under any rates schedule offered under this section.
All applications meeting the published requirements shall be accepted in the order of receipt by PWP, subject to the limitations in subsection (E) of this section.
DC. Said temporary special rate agreements and/or rate schedules may be cancelled by PWP, at any time, on notice to the customer, but in no event shall be in effect for a period exceeding thirty-six (36) months.
ED. The energy sales under this section shall be limited to three percent (3%) of the total system energy sales in megawatt-hours, as reported in PWP's most recent annual report. Each customer group shall be allocated a percentage of the energy sales based on the customer group's contribution to the total system energy sales.
FE. Each participating customer shall be limited to ten percent (10%) of the energy sales within its customer group.
13.04.073 Economic development074 Electric vehicle charging rates. (Schedules EV-1, EV-2, and EV-3, and City-owned retail charging stations) The ratesElectric Vehicle (EV) rate is an optional rate designed to encourage EV adoption and support clean transportation. The terms and conditions of services hereunder shall be as provided by Schedule ED, as follows:
Schedule ED
Economic Development Rates for Medium and Large Commercial and Industrial Customers 216
A. s chedules EV-1, EV-2, and EV-3, and CityCity-Owned Retail Charging Stations as found in the Electric UtilityApplicability.
1.The Economic Development Rate is available to new medium and large commercial and industrial customers that:Resolution.
i. Have a 2012 North American Industry Classification System ("NAICS") code in one of the following categories: Construction (23), Manufacturing (31-33), Information (51), Scientific, Technical, and Professional Services (54), or restaurants (722511 or 722110); ii. Must upgrade the existing building and/or the electrical service interconnection thereto; and A. iii.Are adding a minimum of 50Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge.
A. Electric vehicle charging below 30 kW of projected electrical(Schedule EV-1)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and having a maximum demand of less than 30 k W.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge..
3. Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section
13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.
1. B. 2.For existing mediumElectric vehicle charging at or above 30 kW and large commercialless than 300 kW (Schedule EV-2)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and industrial customers, the projected incremental having a maximum demand must be a minimum of 50kWof greater than or equal to 30 kW and less than 300 kW.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution. and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge. or 10% of existing
C. Electric vehicle charging at or above 300 kW (Schedule EV-3)
1. Applicability. Applies to stand-alone meters or similarly PWP approved metering technology for plug-in electric vehicles charging purposes and having a maximum demand, whichever is greater of greater than or equal to 300 kW.
2. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and the applicable EV charges in accordance with the Electric Utility Rate Resolution.and the applicable energy services charge TOU rate schedule subject to all changes in accordance with the Electric Utility Rate Resolution. The minimum monthly charge shall be equal to the sum of the customer charge and the grid access charge..
DE. City-owned retail charging stations
1. Applicability. Applies to retail customers charging EVs at City-owned stations and shall pay in accordance with the Electric Utility Rate Resolution.
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1.2. Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section
13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.Customers who meet low-income eligibility requirements including EUAP customers, as defined in Section 13.04.046, may receive discounted EV rates in accordance with the Electric Utility Rate Resolution.
3. Customer shall make application to PWP to take service under this schedule. Such application shall indicate whether customer elects to take service under Section 13.04.073(C) (three year rate discount) or Section 13.04.073(D).
4. The City's Economic Development Manager will evaluate the applications to determine whether they meet the proposed business use criteria and the PWP General Manager shall determine whether the customer meets the electrical requirements and qualifies to take service under this Schedule ED.
B. Agreement. Customers shall execute an economic development rate agreement as specified by PWP prior to the effective date of any discount.
C. Option 1 Rate Discount.
1. Except as provided herein, all rates charged will be in accordance with customer's otherwise applicable rate schedule as set forth in the applicable sections of this chapter.
2. The total of the unbundled electric service charges for the distribution, energy, and transmission service charges under the customer's otherwise applicable rate schedule on customer's electric bill associated with the new or incremental load shall be reduced by 20% in the first contract year, 10% in the second contract year; and, 5% in the third and final contract year.
3. For existing customers, the discount will be prorated to reflect only the incremental load that qualifies for the Economic Development Rate.
4. Customer shall compensate PWP for the full cost of electric service connection fees in accordance with Section X of Regulation 21 to qualify for the Rate Discount. Customer must remit 100% of the total estimated cost in advance of PWP performing the work.
D. Option 2 Discounted Interconnection Fees. In lieu of the Rate Discount provided in section C, customer may choose to receive a discount on labor and materials on work performed by PWP to install a new or upgraded electric service connection in accordance with Section X of Regulation 21. The maximum discount for each customer would be $200 per kilowatt of new or incremental load or $100,000, whichever is less. Customer must remit the balance of the total estimated cost in advance of PWP performing the work.
E. Special Provisions.
1. Customer shall comply with all applicable PWP rules and regulations, including without limitation, Regulation 21.
2. Customer must meet Economic Development Rate Qualifying Criteria as determined by the City's Economic Development Manager.
3. Discounts are limited to a maximum of $100,000 per customer over the term of the agreement.
4. The Economic Development Rate will be offered to eligible customers on a first-come first-served basis for three years (from the rate effective date) or until cumulative estimated discounts reach $1,000,000, whichever occurs first.
13.04.080 Standby service. (Schedule SBY)
The raterms and conditions of services hereunder shall be as provided by Schedule S, as follows:SBY, as found in the Electric Utility Rate Resolution.
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A. Applicability. Applicable to customers who in part or in whole have their own generating equipment and who rely on the PWP grid in case of an on-site outage. Standby service shall be furnished solely to the individual contracting customer. Applies to medium and large commercial customers. Character of service shall be three-phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Other voltages and types of service may be approved by the Department for certain specific installations.
B. Customer shall sign a contract for this service, which contract shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer's generating equipment.
C. Service connections shall be made so that at no time will the customer's generating equipment be connected to or operated in parallel with PWP's system. Switching devices used for service connections shall be approved by PWP.
D. Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and (3) the reservation charge.
A. SCHEDULE S
B. Standby Service
C. A.Applicability. Applicable to customers who in part or in whole have their own generating equipment and who contract for standby service from the department.rely on the PWP grid in case of an on-site outage.
Standby service shall be furnished solely to the individual contracting customer in a single enterprise, located entirely on a single, contiguous premise.
D. B.. Applies to medium and large commercial customers. Character of Service. 3service shall be three- phase 240, 480, 120/208 or 277/480 volt, 60 cycle alternating current service. Other voltages and types of service may be approved by the dDepartment for certain specific installations.
E. C.Rate.
F. Effective July 15, 2012:
Per Meter Per Month
All kW of standby capacity $10.87 per kW
2. Energy Charge Energy shall be billed in accordance with the rate schedule which would otherwise apply if
the customer had no generating equipment.
3. Minimum Monthly Charge The demand charge or $201.40, whichever is greater.
4.Application Charge: For each application for new service, or customer originated account change, to be added to the first bill: $5.00.
D.Special Conditions.
1.Contract Required. Customer shall sign a contract for this service, which contract shall state the number of kW of standby capacity required. "Standby capacity" shall not exceed the nameplate rating of the customer's generating equipment.
2.Service Connections. B. Service connections shall be made so that at no time will the customer's generating equipment be connected to or operated in parallel with PWP's system. Switching devices used for service connections shall be approved by PWP.
C.Customer shall pay the sum of the following charges (1) customer charge, (2) grid access charge, and (3) the reservation charge.
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13.04.085 Unmetered rates—Nnon-demand. below 30 kW (Schedule CE-1) The raterms and conditions of services hereunder shall be as provided by Schedule CE-1—Non, non- demand, as follows:found in the Electric Utility Rate Resolution.
SCHEDULE CE 1
Non-Demand
A. Applicability. Applies to any unmetered telecommunications devices and other equipment with less than 30 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the City.
B. Monthly energy consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
C. Customer shall pay the sum of the following charges (1) customer charge for either (a) single-phase service or (b) three-phase service. (2) distribution charge, (3) grid access charge, (4) energy services charge based on the monthly energy consumption, (5) transmission services charge, and (6) public benefit charge.
D. Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
E. Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
F. Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
G. From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide City personnel with access to customer's equipment and provide assistance as necessary to complete the audit.
A. A.Applicability. Applies to any unmetered telecommunications devices and other equipment with less than 30 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the cCity.
B. B.Monthly Energy Consumptionenergy consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
C. Rates. Customer shall pay the sum of the following charges:
(1. C) c ustomer charge per connection per month:
Singlefor either (a) single-phase service: $14.16
Three or (b) three-phase service: $19.07
. (2. D ) distribution charge for all kWh per month:
$0.04475 per kWh
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, (3. Transmission Services Charge. Customer shall pay a) grid access charge, (4) energy services charge based on the monthly energy consumption, (5) transmission services charge in accordance with Section 13.04.170 for each kWh delivered.
4. Energy Services Charge. Customer shall pay an energy service charge as follows:
Seasonal Flat Rate:
Season Energy Service Charge per kWh
Summer $0.06901
Winter $0.06030
a.Power Cost Adjustment. Customer shall pay a power cost adjustment in accordance with Section
13.04.173.
5.Public Benefit Charge. Customer shall pay a, and (6) public benefit charge in accordance with Section
13.04.230 for each kWh delivered. .
D. General Conditions.
C. 1.Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
D. 2.Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
1. 3.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
E. 4.From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide cCity personnel with access to customer's equipment and provide assistance as necessary to complete the audit.
13.04.087 Unmetered rates—Demand.demand at or above 30 kW (Schedule CE-2) The raterms and conditions of services hereunder shall be as provided by Schedule CE 2—Demand, as follows:
SCHEDULE CE -2, demand, as found in the Electric Utility Rate Resolution.
Demand
A. A.Applicability. Applies to any unmetered telecommunications devices and other equipment with 30 kW demand or greater, but less than 300 kW demand where metering installations would be impractical, unavailable, uneconomical or restricted by the cCity.
B. B.Billing Determinants.
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2.1. 1.Monthly Energy Consumption. PWP shall determine the monthly energy consumption by multiplying the number of hours in the billing period by the maximum hourly energy consumption of the unmetered equipment based on the manufacturer's specifications and operating characteristics. For the purpose of this schedule, monthly energy consumption shall be deemed to be the kWh delivered.
3.2. 2.Monthly Billing Demand. PWP shall determine the monthly billing demand based on the maximum demand (kW) of the telecommunications devices and other equipment as set forth in the manufacturer's specifications.
C. Rates. Customer shall pay the sum of the following charges:
(1. Customer Charge Per Connection Per Month:
Customer) customer charge: $60.22
for either (a) single-phase service or (b) three-phase service. (2.Distribution Charge. The) distribution rate for customer shall be as follows:
All kilowatts of demand: $10.87 per kW
4.3. charge, (3.Transmission Services Charge. Customer shall pay a) grid access charge, (4) energy services charge based on monthly energy consumption, and (5) transmission services charge in accordance with Section 13.04.170 for each kWh delivered. .
4. Energy Services Charge. Customer shall pay an energy service charge as follows:
Seasonal Flat Rate:
Season Energy Services Charge per kWh
Summer $0.07338
Winter $0.06213
a. Power Cost Adjustment. Customers shall pay a power cost adjustment in accordance with Section 13.04.173.
5. Public Benefit Charge. Customer shall pay a public benefit charge in accordance with Section
13.04.230 for each kWh delivered.
D. General Conditions.
5.4. 1.Customer shall be solely responsible to install, own, operate, and maintain all equipment. City shall not be responsible for any damage to customer's equipment under any circumstances.
6.5. 2.Customer and PWP shall mutually agree upon each location for unmetered telecommunications devices and other equipment installations. Each location or connection shall be deemed a separate account.
F. 3.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
6. 4.Customer shall not increase connected load or change the character of telecommunications devices and other equipment without providing written prior notice to PWP of at least 30 days. Customer shall furnish PWP written notice of any change in the connection configuration, rated electrical load, or operating characteristics of such equipment. In event customer does not provide such written notice, PWP may estimate customer's actual energy use and back bill the customer.
7. From time to time, PWP may audit customer's equipment using a temporary meter. Customer's fixed electric rate shall be adjusted based upon the results of the audit. Customer shall provide cCity personnel 222
with access to customer's equipment and provide assistance as necessary to complete the audit within seven calendar days of written request.
13.04.090 Street lighting and traffic signal service. (Schedule SL) The raterms and conditions of services hereunder shall be as provided by Schedule SL, as follows:found in the Electric Utility Rate Resolution.
SCHEDULE SL
Street Lighting and Traffic Signals
A. A.Applicability. Applies to outdoor street, highway and area lights and traffic signals, whether publicly or privately owned, where the poles, electrolier standards and lighting equipment are owned by the customer.
For such lights as are burned from 30 minutes after sunset to 30 minutes before sunrise, 4140 hours of service per year will be used for cost calculation purpose.
B. B.Rate. Unmetered street lighting and signs not included in the flat rate section will be billed under the metered rate section using the hours of service per year set forth in subsection A. Unmetered load, including without limitation, traffic signals, street lighting, signs with extended hours of operation, bus shelters, and irrigation controllers will be billed under the metered rate section by extrapolating usage from a sample test metering period. All services covered under this section, whether billed under the flat rate or metered rate section shall also be subject to the transmission services charge and power adjustment chargebilled in accordance with Sections 13.04.170 and 13.04.173. the Electric Utility Rate Resolution.
Effective July 15, 2012:
1. Flat Rate—Lamp Size Monthly Charge
Per Lamp ($)
Incandescent
1,000 lumens $0.94
1,500 lumens 1.11
2,500 lumens 1.95
4,000 lumens 3.14
6,000 lumens 4.47
10,000 lumens 6.79
67 watts 0.86
69 watts 0.88
103 watts 1.30
150 watts 1.89
202 watts 2.54
303 watts 3.80
Mercury Vapor
3,500 lumens 1.61
7,000 lumens 2.64
11,000 lumens 3.66
20,000 lumens 5.80
35,000 lumens 9.81
54,000 lumens 13.87
Fluorescent
213 watts 2.68
248 watts 3.14
High Pressure Sodium
35 watts 0.51
50 watts 0.72
70 watts 1.28
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100 watts 1.76
150 watts 2.43
200 watts 3.09
250 watts 3.94
310 watts 4.81
400 watts 5.98
4—60 watts unit bus stop 4.82
2—40 watts unit bus stop 4.82
Metal Halide 3.99
2. Metered Distribution Rate.
a. For metered street lighting, all energy will be billed at $0.03923 per kWh. b. For metered traffic signals and signs, all energy will be billed at $0.05807 per kWh.
3. Unmetered Distribution Rate.
a. For unmetered traffic signals and signs, all energy will be billed at $0.05807 per kWh.
4. Transmission Services Charge. Customers taking service under Schedule SL shall pay a transmission services charge for each kWh delivered to in accordance with Section 13.04.170.
5. Energy Services Charge. Customers taking service under Schedule SL shall pay energy services charge of $0.065 for each kWh delivered.
6. Power Cost Adjustment. Customers taking service under Schedule SL shall pay a PCA, as provided in Section 13.04.173.
13.04.100 Service regulations and charges.
A. The general manager of the water and power departmentDepartment shall, from time to time, approve service regulations and procedures relating to conditions of service, application, administration and interpretation of rates, or to any other provision of this chapter; provided, however, that any proposed new or revised charges or fees for reconnections and for various special services not otherwise provided for in this chapter shall be effective upon adoption thereof by resolution of the city councilCity Council. No later than 30 days prior to the effective date of any amendments to such regulations, the proposed amendments shall be posted on PWP's website and the city councilCity Council shall be notified in writing of such proposed amendments.
B. On failure to comply with the service regulations of the dDepartment, or to pay charges, or to comply with penalties imposed for such failure as herein provided, electric service may be turned off until the regulations, charges, or said penalties are complied with or payment is made of the amount due.
13.04.110 Meter and service installation.
All meters and services shall be installed and located in accordance with specifications and drawings entitled "Electricdetailed in the Electrical Service Requirements, Regulation No. 21." Regulations set forth by PWP. In the event that meter and service connections are not so installed, the dDepartment will delay making service connections to such premises until the service requirements are satisfied. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. 224
All meters and services shall be installed and located in accordance with specifications and drawings detailed in the Electrical Service Requirements Regulations set forth by PWP. In the event that meter and service connections are not so installed, the Department will delay making service connections to such premises until the service requirements are satisfied. Demand meters will be adjusted to measure the maximum integrated demand over a 15-minute interval, or if the demand is of an intermittent character, PWP may adjust the meters to measure the demand during a shorter interval. Advanced Meters with Interval Read Capability will be the standard of installation, customers wishing to opt out are subject to fees as stated in the Utility Rate Resolution.
Advanced Meters with Interval Read Capability will be the standard of installation, customers wishing to opt out are subject to fees as stated in the Utility Rate Resolution.
13.04.120 Inspections.
A. Entry on Premises. Department employees may enter private premises to make inspections or examinations of wires, fixtures or attachments, to read meters, or to determine if there has been unlawful tampering with department equipment, devices or seals, or unlawful installation of devices to evade department metering of energy. Department employees whose duty it is to enter upon private premises will be provided with a badge or other identification. Such identification shall be shown to customer at the time of entry on customer's premises.
B. Interference with Authorized Employees. The general manager may discontinue service of electrical energy to any premises after written notice to the customer of his intent to do so, for the following causes:
1. The customer has refused admittance to an authorized employee, at a reasonable hour, in the performance of his duty; or
2. The customer, by his personal conduct, or by maintaining a dangerous condition or vicious animal upon the premises, has hindered or interfered with an authorized employee in the performance of his duty.
The general manager shall serve such notice by mailing one copy to the customer at his last known address, and one copy to the premises, if a different address. The general manager need not reconnect the service until the customer has given satisfactory assurance to the general manager that an authorized employee will not be interfered with or hindered, or refused admittance, in the performance of his duty.
C. Access to electric meters at the customers facilities shall be provided at all times. If access to the customers meter is prohibited by a locking device on a gate, door or other access entries, customers shall provide PWP with a key to allow access by meter readers or other authorized personnel for the purpose of inspecting and/or maintaining and/or reading the meter. PWP is authorized to install at the customer's facility a lock box accessible only to PWP authorized personnel for the purpose of securing the key on site to gain ready access to the customer's electric meter.
D. PWP may inspect or test any power equipment and estimate or measure the demand, starting currents, power factor or other characteristics of such equipment to determine proper billing or compliance with the requirements of this chapter.
13.04.125 Private underground electric vaults.
A. On reasonable notice, typically within five business days, the dDepartment may enter upon private property to inspect, repair or replace any private underground electrical vault. It shall be the duty of the owner of a private underground vault to: (i) make the vault freely accessible to department employeesDepartment employees; (ii) maintain the vault in good repair free from water or other unsafe conditions; and (iii) comply with all state and local regulations applicable to underground electrical vaults. Any vault which fails to meet these requirements is hereby deemed a nuisance per se.
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B. In event the condition of a private underground vault does not meet the requirements set forth in subsection A of this section, the dDepartment may proceed with code enforcement proceedings pursuant to Chapters
1.24, 1.26 or 1.30 of the Pasadena Municipal Code. The dDepartment may also, in its discretion, remediate the condition of any private underground vault. Prior to such remediation, the dDepartment shall notify the vault owner of the problems to correct and the time for correcting them. If the problems are not timely corrected, the dDepartment shall notify the vault owner of the dDepartment's proposed solutions to the problems and the department's cost to complete them. The vault owner shall have the right to contest the dDepartment's proposed action by filing an administrative appeal with the general manager of the dDepartment not later than ten days from the date set forth on the dDepartment's notice. In event an appeal is not timely taken, the dDepartment's proposed action shall be the final administrative decision and no resort to the courts may be taken therefrom due to failure to exhaust remedies.
C. All costs of remediating the condition of a private electrical vault shall be the responsibility of the vault owner.
Such costs shall be billed to the vault owner according to the normal billing procedures and requirements applicable to department customers. In event the vault owner does not timely pay in full, the dDepartment may exercise any remedies available to it under this code or other law, including shut-off of electrical service to the premises served by the private underground vault. Costs incurred by the dDepartment in remediating the condition of a private underground vault shall also be recoverable in any proceeding brought pursuant to Chapters 1.24, 1.26 or 1.30 of the Pasadena Municipal Code.
13.04.130 City not liable for damages relating to delivery failures.
The cCity is not liable for any damage to persons or property caused in any manner by the use or application of electric current, nor is it liable for any damage caused by its failure to deliver current, proper voltage or frequency, all or part of 3three-phase current, or electrical energy for any length of time.
13.04.140 Financial responsibility—Delinquency penalty.
A. Customer Liability. The customer is responsible for and shall pay the cCity for all electrical energy delivered to the premises as registered on the cCity meter. The meter bill is due and payable when rendered, and is delinquent 3021 days after the date rendered. If delinquent bills for any electrical service are not paid upon presentation, such service may be discontinued without further notice. In addition, there shall be assessed a penalty assessment for delinquent bills pursuant to Section 1.08.080. The amount of such penalty shall be as set forth on the general fee schedule.
B. Responsibility for Schedule. It is the responsibility of the customer to determine that he is being served under the proper schedule. In the event the customer feels he is not being so served, he shall file with the dDepartment a written statement, stating the reasons therefor. The dDepartment shall then promptly make an investigation and shall inform the customer in writing of its conclusions, and shall adjust the rate or not, accordingly. Department is not liable for excess charges to customer prior to the time customer files the written statement.
C. Deposits. The general manager of the dDepartment may require a deposit in reasonable amount to guarantee payment for electrical energy to be used subsequent to date of demand for such deposit. If any customer fails to make such deposit after demand therefor, electrical service may be discontinued until the deposit required has been made.
D. Reconnection Charge. If electrical service is disconnected for nonpayment of bills, nonpayment of required deposit, by customer request or because of interference with authorized employees of departmentPWP, the appropriate reconnection and special service charges, in addition to all previously accrued charges, shall be made prior to reconnection of service.
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13.04.150 Rate schedule changes.
A customer qualifying for a particular rate schedule will not be transferred to another rate schedule because of temporary or seasonal conditions for the purpose of reducing the minimum or energy charges. Unless there is a major change in the customer's type of load, a particular rate will continue in effect for at least 12 months. except upon the adoption of Interval Read Capable Meters for billing, at which time customer may be automatically enrolled in the Time-of-Use rates. If a major change in type of load occurs in less than 12 months, the dDepartment may charge and collect $3.00 for each meter affected.
13.04.160 Meter readings combined.
The municipal light and power departmentThe Department will not ordinarily combine meter readings for billing purposes. However, in the event a consumer has brought out all of his electric leads to a central and convenient location and more than one meter of a given class is deemed necessary by the dDepartment, the dDepartment may combine the readings of such meters for billing purposes.
13.04.170 Transmission services charge.
A. The transmission services charge (TSC) is designed to capture the transmission revenue requirement (TRR) and net cost savings from joining participating transmission owner (PTO) with California Independent System Operator (CAISO) as defined in subsection (C)(4) of this section and shall be based on actual data obtained from the cCity's accounting system, forecast data obtained from the annual operational planbudget approved by the city councilCity Council, and updated forecast data prepared monthly by PWP.
B. PWP shall calculate the TSC on a quarterlyan as needed basis, and the revised value for this charge shall remain in effect for no less than three months.
C. For purposes of this section, the following definitions apply:
"Full service customers" means customers who choose PWP as their energy supplier.
1. "Net cost savings from being a participating transmission owner with California Independent System Operator (NCS PTO CAISO)") means all PTO revenues received from CAISO, including, but not limited to, PTO TRR, net firm transmission right (FTR) revenues, and high voltage wheeling revenues less all expenses paid to CAISO including, but not limited to, transmission access charges (TAC) and grid- management charges. NCS PTO CAISO shall be subject to an adjustment by CAISO transmission revenue balancing adjustment account.
E. "System energy sales" means the estimated total energy sales delivered to all customers.
2. "Transmission revenue requirement" means is the sum of all costs related to the high-voltage transmission of energy, including, but not limited to, all transmission contracts, wheeling fees, pertinent labor and operating costs, associated general fund transfer, operating margin, debt service, and ISOIndependent System Operator access fees, less the sum of all wholesale revenues received in connection with the sale of any transmission entitlements.
D. The transmission services charge shall be calculated quarterly as follows:
1. Commencing July 1, 2002, a separate transmission services charge fund (TSCF)TSC account shall be maintained for balancing costs and revenues associated with high-voltage transmission and related services. Any transmission access charge fund (TACF)TAC over collection or under collection existing on July 1, 2002 shall be depositedmaintained in the TSCFTSC account balance.
2. The TSCF account balance shall be calculated as the sum of actual revenues from the TSC less the actual TRR plus NCS PTO CAISO.
3. The transmission services charge shall be calculated based on the forecasts for the following twelve months for TRR, NCS PTO CAISO, system energy sales, and the TSCF balance as follows:
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[TRR Forecast - NCS PTO CAISO Forecast - TSCF Balance]
[System Energy Sales Forecast]
4. The result of the formulaTSC shall be calculated and rounded to the nearest mill per kilowatt-hour. This shall be the transmission service charge to be implemented.
5. The transmission services charge for customers served under Schedules M-2 and L-2 or forwhose service are metered and delivered at 17kV 4 kV or higher shall be reduced by $ 0.00019 per kWh.
13.04.173 Power cost adjustment. (PCA)
A. A Power Cost Adjustment (PCA) shall be added to the energy services charge set forth in the service schedules of this chapterElectric Utility Rate Resolution. Each customer shall pay the applicable energy services charge plus a PCA for each kWh delivered to the customer.
B. The PCA shall be based on actual data obtained from the cCity's accounting system, forecast data obtained from the annual operational planbudget approved by the City Council, and updated forecast data prepared as frequently as monthly by PWP.
C. PWP shall recalculate the PCA each monthas frequently as monthly, and the resulting values for these charges shall be automatically implemented on the first day of the following month.
D. For purposes of this section, the following definitions apply:
1. 1."Energy Costs" meanscosts" is the sum of all costs related to the procurement and generation of energy for delivery to Full ServiceRetail Customers, including, but not limited to, Power Production Costs and Purchased Power Costs, operating margin, debt service and the general fund transfer associated with these costs.
2. 2."Energy Cost Forecast" means cost forecast" is the forecast of projected Energy Costsenergy costs for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
3. 3."Energy Services Charge Revenue Forecast" meansservices charge revenue forecast" is the forecast of projected Energy Services Charge Revenue energy services charge revenue for the twelve months immediately following the last actual billing period. The energy services charge set forth in the schedules reflects the energy cost forecast as of July 1, 2002, based on the approved rate restructuring plan approved by the City Council adjusted to each customer group's load profile, and shall remain in effect until modified by Ordinance.
4. 4."Energy revenue credit" is a percentage of the Wholesale Net Incomewholesale net income used to reduce the Energy Charge. The Energy Revenue Credit shall be appliedenergy charge. The energy revenue credit is 75% of the wholesale net income, when the Wholesale Net Income is greater than zero and shall be determined at least quarterly based on the actual accounting data as follows: (i) 75% of the Wholesale Net Income shall be applied as a credit; (ii) additional amounts may be authorized by Council Resolution.
5. 5."Energy revenue forecast" meansis the forecast of projected Energy Revenue Creditsenergy revenue credits for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
6. 6."Fuel costs" means the sum of the cost of fuel gas consumed, the cost of fuel oil consumed, and the cost of procuring, scheduling, testing and in-plant handling of that fuel gas and fuel oil. Fuel oil includes both residual fuel oil and distillate fuel oil.
7. "Full service customers" shall mean customers who choose PWP as their energy supplier. 228
7. 8."Full service energy"Retail Energy sales forecast" meansis the forecast of projected energy sales (in kilowatt-hours) to Full Service Customers for the twelve months immediately following the last actual billing period. This forecast shall be updated monthly by PWP.
8. 9."Power production costs" meansis the sum of all costs for the generation of electric energy at facilities owned and operated by PWP, including, but not limited to, Fuel Costs, labor, operating and maintenance expenses, materials, and emissions credits.
10. "Purchased power costs" meansis the cost of energy and ancillary services, including, but not limited to, capacity and energy charges from third parties and all non-transmission charges charged by the California Independent System Operator (ISO).
11. "System energy sales" means the estimated total energy sales delivered to all customers.
12. "Wholesale net income" means the sum of revenues realized from wholesale energy and ancillary service sales, less the associated production cost and purchased power cost attributable to the wholesale sales.
[E—G.Reserved.]
H. The PCA shall be added to the energy service charge set forth in the service schedules, and shall be calculated monthly as follows:
1. Commencing July 1, 2002, a separate Energy Services Charge Fund (ESCF)energy services account balance shall be maintained for balancing costs, revenues, and credits associated with energy delivered to Full Service Customers. Any Energy Charge Fund over collection or under collection existing on July 1, 2002 shall be deposited in the ESCF balance.retail customers.
2. The ESCF account balance shall be calculated as the sum of actual revenues from the Energy Services Charge, the Energy Revenue Credit, and any other credits authorized by the City Council, less the actual Energy Costs inched.
3. Reserved.
4. The Energy Services Chargeenergy services charge shall be calculated based on the Energy Cost Forecast, Energy Revenue Credit Forecast, Full Service Energy Sales Forecast, and the ESCFenergy cost forecast, energy revenue credit forecast, retail service energy sales forecast, and the energy services charge account balance as follows:
[Energy Cost Forecast - Energy Revenue Credit Forecast - Fund Balance] [Full Service Energy Sales Forecast]
5[energy cost forecast - energy revenue credit forecast – energy services charge account balance] [retail energy sales forecast]
3. The PCA shall be calculated based on the twelve month forecast of Energy Services Revenue, Energy Cost, Energy Revenue Credit, Full Service Energy Sales, ESCFenergy services revenue, energy cost, energy revenue credit, retail energy sales, energy services charge account balance and Fund Reserve Targetaccount reserve levels as follows:
[Energy Cost Forecast - Energy Revenue Credit Forecast - Fund Balance - Energy Services Revenue Forecast + Reserve Target]
[Full Service Energy Sales Forecast]
6[energy cost forecast - energy revenue credit forecast – energy services charge account balance - energy services revenue forecast + reserve levels] [retail energy sales forecast]
4. The result of the formula shall be rounded to the nearest millone thousandth per kilowatt-hour. This shall be the PCA to be implemented.
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13.04.178 Self-generation service. (Schedule SG)
Schedule SG
Self-Generation Service
A.Availability. Available and mandatoryTo encourage the development of local renewable energy generation by customer-generators, self-generation service shall be as provided by Schedule SG as follows and as found in the Electric Utility Rate Resolution.
A. Applicability.
1. Applies to customers with self-generation or cogeneration not less than one megawatt capacity and billing demand not less than 300 kW.
2. Customers shall sign an interconnection and metering agreement with PWP.
3. This schedule will be applied to each meter at point of delivery or receipt, and in no event will meter readings be combined.B.Rates.
B. Self-generation service.
1. Rates for this service shall be the same as for the scheduletime-of-use rates 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 (M-l).
2. In except, (1) in each month, billing demand will be the greater of the maximum fifteen15 minute kW of the absolute net power that theelectricity delivered to customer received from or injected into the PWP power system during the current month or preceding eleven11 months.
3. In and (2) in each month, the billing determinant for the Transmission Services Chargetransmission 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 determinants2. Customer 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 energya credit. a. The in an amount equal to the net electricity delivered to PWP multiplied by the applicable energy credit periods shall be one month for customers on seasonal flat rates and TOU periods for customers on TOU ratesservices charge.
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.
c. 3. Billing.
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a. Customers shall receive a monthly or bi-monthly bill from PWP. Customers shall pay the outstanding balance, if any, owed to PWP.
b. Credits shall be given to the customer in the form of offsets to charges on the customer's bill.future electric bills. If, in any month, a customer's electric credits (including any credit carry-forwards from previous months exceed that customer's charges,) the net credit will carry forward to the customer's bill for the following twelve months. Credits shall expire upon termination of electric service.
64. The customer shall be responsible to reimburse PWP for any and all upgrades to PWP's power system which are necessary due to the customer's generation, including, without limitation, metering equipment.
C. Conditions:
1. The above service is subject to PWP rules and regulations.
2. This schedule will be applied to each meter at point of delivery or receipt, and in no event will meter readings be combined.
3. Customers shall sign an interconnection agreement with PWP.
4. Customers shall comply with Regulation 23.
13.04.179 Green power service.
(Schedule GP)
Green Power Service
A. Applicability. The charges set forth in this schedule apply to those customers who choose green power service.
By subscribing to green power service customers will accelerate the procurement and development of renewable energy resources by paying a green power premium which PWP will then apply to green power procurement on behalf of such customers. Customers choosing this service shall either select a 100% Green power service option or nominate the amount of green service in blocks of 100 kWh per month. All other rates and charges for electric services apply to these customers as specified in their otherwise applicable schedule. "Green power" as used in this section shall mean energy procured from an "Eligible renewable energy resource" as defined in California Public Utility Code Section 399.12(e) to serve customers that have selected Green power service.
B. Green Power Premium. The Green Power Premium shall be $0.018 per kWh of metered electricity use for customers choosing 100% Green power service, or, $1.80 per month for each 100 kWh block of green power nomination.
C. For customers enrolling after March 1, 2026, the Green Power Premium shall be established in the Electric Utility Rate Resolution as of the enrollment date. the value of portfolio content category one (PCC1) renewable energy credits (RECs) based on recent actual transactions by Pasadena Water and Power ($/MWh) C. Use of Green Power. Consistent with PWP's Renewable Portfolio Standard Procurement Plan and Enforcement Program, as may be amended from time to time, PWP shall account for energy procured on behalf of Green power service customers separately from that procured for non-Green power service customers, and shall not utilize the renewable attributes associated with Green power procurement for compliance purposes.
D. The Green Power Premium shall not be included as gross income for purposes of calculating the light and power fund transfer under Sections 1407 and 1408 of the Charter. 231
13.04.180 Theft of energy.
A. In applying for service the customer agrees that the department may install and maintain equipment on the customer's premises for the proper metering of energy and distribution of current to prevent the theft thereof. Any customer who tampers with department's equipment to avoid payment of the rates herein prescribed, or to reconnect service that has been disconnected by department, is liable to punishment therefor pursuant to law. Upon discovery of such tampering, the general manager may cause the service to be disconnected and remove all equipment installed by the department forthwith. If the premises is vacant or the equipment installed is no longer needed, such equipment may be removed at any time upon order of the general manager of the department.
B. Any person or agency apprehended using electricity without permission from a power line, electrical service, or other system connection will be charged for each occurrence a minimum of $300.00, or such other charge as established by resolution Electric Utility Rate Resolution of the city councilCity Council, plus the cost of electricity estimated to have been used. Investigation costs may be added thereto at the option of the general manager.
13.04.190 Apparatus causing interference.
The department may disconnect any service on its lines to which is connected any device or apparatus causing a distortion of the wave form of the voltage or current supplied, or generating or causing high frequency electrical radiation or other electrical disturbance, which interferes with radio or television broadcast reception or with other forms of communication, or with the operation of any of department's protection or control facilities.
The owner of such device or apparatus shall have a reasonable time within which to repair, modify or adjust, or to agree to pay department's costs of devices, apparatus and installation, to prevent interference.
13.04.200 Billing procedure.
A. The rates established apply basically to monthly periods. The meter reading dates shall be determined by the dDepartment and bills will be rendered monthly or bimonthly at the option of the department. Bimonthly bills will be computed by doubling the monthly energy block and the monthly customer or minimum charge. When service to a customer is initiated or terminated between regular meter reading dates for a particular premises, the bill will be prorated on a basis established by the general manager.
B. Notwithstanding anything in this chapter to the contrary, billing may be made and charges collected for service furnished hereunder to any customer at such times as the department considers to be in the best interests of the department and the customer so billed. Charges billed for a period of more than 1one month are made as though monthly meter readings had been taken and had shown equal use of service each month within the period and charges had been billed monthly thereon.
13.04.210 Gaseous lighting units
All vapor or discharge tube type lighting units, such as neon, argon and fluorescent lighting, shall include power factor corrective equipment so that the overall power factor shall not be less than 90%. All installations of corrective equipment rated at 250 volt-amperes or more shall be approved by the Department.
13.04.220 Added load.
Customers shall notify and secure approval of dDepartment before adding any power load of 3 HPhp or appliance load of 3 KW or greater to an existing service. 232
13.04.230 Public benefit charge.
A. Pursuant to the requirements of Section 385 of the Public Utilities Code of the state of California, there is established a nonbypassable, usage based public benefit charge on local distribution service for each kilowatt- hour delivered to the customer.
B. The public benefit charge shall be based on data obtained from the city's accounting system and updated forecast data prepared quarterly by the department.
C. The departmentDepartment shall recalculate the public benefit charge quarterlyannually and the resulting value for this charge shall be automatically implemented on the first day of the following month.
DC. For the purpose of calculating the public benefit charge, the following definitions shall apply:
1. "Public benefit cost" means expenditures pursuant to subsections (G)(1) through (G)(4), inclusive.
2. "Public benefit cost forecast" means the forecast of public benefit cost for the twelve months immediately following the last billing period.
3. "Public benefit fund balance" means the sum of all prior revenues from the public benefit charge, less the sum of all prior public benefit cost and committed public benefit cost.
4. "Full service Retail energy sales forecast" means the forecast of projected energy sales (in kilowatt-hours) to all electric customers taking service under this chapter for the twelve months immediately following the last billing period.
ED. The public benefit charge shall be calculated based on the public benefit cost forecast, the public benefit fund balance, and the fullretail service energy sales forecast as follows: the public benefit cost forecast minus the public benefit fund balance, which sum shall be divided by the fullretail service energy sales forecast. The result shall be rounded to the nearest mill per kilowatt-hour.
FE. In no event shall the public benefit charge be less than $0.00271 per kilowatt-hour.
GF. Moneys collected through the public benefit charge will be used exclusively to fund investments in any or all of the following:
1. Cost-effective demand -side management services to promote energy efficiency, energy conservation, and electric demand reduction;
2. New investment or incentives to promote the installation and use of renewable energy resources and technologies consistent with existing statutes and regulations which promote those resources and technologies;
3. Research, development and demonstration programs for the public interest to advance science or technology which is not adequately provided by competitive and regulated markets; and
4. Services provided for low-income electricity customer, including but not limited to, targeted energy efficiency service and rate discounts.
HG. This public benefit charge shall not be subject to any taxes or surcharges imposed pursuant to the Pasadena Municipal Code.
IH. This public benefit charge shall not be included as gross income for purposes of calculating the light and power fund transfer under Sections 1407 andSection 1408 of the Charter.
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
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 Ch $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 ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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Phase 3
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ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
13.04.060 Grid Access Charge per meter per month N/A $250.00000 $250.00000 $250.00000
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 Ch 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 Ch $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 Ch 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 C $7,175.91000 N/A N/A N/A 2 of 6
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Phase 2
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Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 C 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 C 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 C $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 C 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
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 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
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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 5 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(March 2027)
Phase 3
(March 2028)
ATTACHMENT D: DRAFT RATE SCHEDULE ALTERNATIVE 3
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
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MUNICIPAL COD MUNICIPAL 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 Char $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 E: REVISED DRAFT RATE SCHEDULE ALTERNATIVE 1 1 of 5
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MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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 Char 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 Char $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 Char 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 Cha $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 Cha N/A $7,695.00000 $8,440.000002 of 5 241
MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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 Cha 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 Cha $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 Cha 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 5 242
MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT 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
13.04.178 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
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
13.04.179 Green power service (GP)
13.04.179 Green power premium per kWh $0.01800
4 of 5
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MUNICIPAL COD MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 Phase 2 ATTACHMENT E: REVISED DRAFT RATE SCHEDULE ALTERNATIVE 1
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
244
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
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 Ch $756.10000 N/A N/A N/A
13.04.060 Medium commerical service - secondary (M-2)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2 1 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 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
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 Ch 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 Ch $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 Ch 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 C $7,175.91000 N/A N/A N/A 2 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED 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 C 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 C 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 C $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 C 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
3 of 6
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2
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 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
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MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED 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 5 of 6
249
MUNICIPAL MUNICIPAL CODE DESCRIPTION Current Rates Phase 1 (March 2026)
Phase 2
(October 2026)
Phase 3
(March 2027)
ATTACHMENT E: DRAFT REVISED RATE SCHEDULE ALTERNATIVE 2
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
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ITEM #2
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PA
S AD EN A W AT ER AN D PO W ER
MEMORANDUM
January 13, 2026
To: Muni
cipal Services Committee
From:
David M. Reyes
General Manager
Subj
ect: Raymond Groundwater Basin Update
Pas
adena Water and Power (“PWP”) will present an update to the Municipal Services Committee on the Raymond Groundwater Basin (“Raymond Basin”). This is presented as an informational item.
The pr
esentation includes a brief history of the Raymond Basin, an overview of current conditions, and programs , projects, and future actions to continue to enhance the sustainability of this critical resource. The health of this groundwater basin is essential to support the health and safety of the community, particularly as the region faces increasingly extreme climate and emergencies.
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