HomeMy WebLinkAbout2022-06-08 Utilities Advisory Commission Agenda PacketMATERIALS RELATED TO AN ITEM ON THIS AGENDA SUBMITTED TO THE COMMISSION AFTER DISTRIBUTION OF THE AGENDA
PACKET ARE AVAILABLE FOR PUBLIC INSPECTION IN THE UTILITIES DEPARTMENT AT PALO ALTO CITY HALL, 250 HAMILTON AVE.
DURING NORMAL BUSINESS HOURS.
AMERICANS WITH DISABILITY ACT (ADA)
Persons with disabilities who require auxiliary aids or services in using City facilities, services or programs or who would like information on the
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UTILITIES ADVISORY COMMISSION – SPECIAL MEETING
JUNE 8, 2022 – 6:00 PM
CHAMBERS/ZOOM Webinar
NOTICE IS POSTED IN ACCORDANCE WITH GOVERNMENT CODE SECTION 54954.2(a) OR 54956
Supporting materials are available online at https://www.cityofpaloalto.org/gov/boards/uac/default.asp on Thursday, 5 days
preceding the meeting.
Join Zoom Webinar Here Meeting ID: 966 9129 7246 Phone: 1 (669) 900-6833
Pursuant to AB 361 Utilities Advisory Commission meetings will be held as “hybrid” meetings with the
option to attend by teleconference or in person. To maximize public safety while still maintaining
transparency and public access, members of the public can choose to participate from home or attend in
person. Members of the public who wish to participate by computer or phone can find the instructions
at the end of this agenda. Masks are strongly encouraged if attending in person. The meeting will be
broadcast on Cable TV Channel 26, live on Midpen Media Center at https://midpenmedia.org, and live
on YouTube at https://www.youtube.com/c/cityofpaloalto. Members of the public who wish to
participate by computer or phone can find the instructions at the end of this agenda.
I. ROLL CALL 6:00 pm – 6:05 pm
II. AGENDA REVIEW AND REVISIONS 6:05 pm – 6:10 pm
III. ORAL COMMUNICATIONS 6:00 pm – 6:25 pm
Members of the public are invited to address the Commission on any subject not on the agenda. A reasonable time
restriction may be imposed at the discretion of the Chair. State law generally precludes the UAC from discussing or acting
upon any topic initially presented during oral communication.
IV. APPROVAL OF THE MINUTES 6:25 pm – 6:30 pm
Approval of the Minutes of the Utilities Advisory Commission Meeting held on May 4, 2022
V. UNFINISHED BUSINESS
VI. UTILITIES DIRECTOR REPORT 6:30 pm – 6:45 pm
VII. NEW BUSINESS
1. Adoption of a Resolution Authorizing Use of Teleconferencing for Utilities Advisory
Commission Meetings During Covid-19 State of Emergency (Action) 6:45 pm – 6:55 pm
2. Staff Recommends That the Utilities Advisory Commission Recommend the City Council
Adopt the 2022 Annual Water Shortage Assessment Report (Action) 6:55 pm – 7:25 pm
Chairman: Lisa Forssell Vice Chair: Lauren Segal Commissioners: John Bowie, A.C. Johnston, Phil Metz, Greg Scharff, and Loren Smith Council Liaison: Alison Cormack
MATERIALS RELATED TO AN ITEM ON THIS AGENDA SUBMITTED TO THE COMMISSION AFTER DISTRIBUTION OF THE AGENDA
PACKET ARE AVAILABLE FOR PUBLIC INSPECTION IN THE UTILITIES DEPARTMENT AT PALO ALTO CITY HALL, 250 HAMILTON AVE.
DURING NORMAL BUSINESS HOURS.
AMERICANS WITH DISABILITY ACT (ADA)
Persons with disabilities who require auxiliary aids or services in using City facilities, services or programs or who would like information on the
City’s compliance with the Americans with Disabilities Act (ADA) of 1990, may contact (650) 329-2550 (Voice) 24 hours in advance.
3. Discussion and Update to the 2022 Wildfire Safety Mitigation Plan (Discussion) 7:25 pm –
7:45 pm
4. Staff Request for UAC Feedback on the Development of the Electric Utility’s Integrated
Resource Plan (Discussion) 7:45 pm – 8:45 pm
5. Discussion of Advanced Metering Infrastructure Opt-Out and Electric Meter Remote
Disconnect and Reconnect Policies (Discussion) 8:45 pm – 9:15 pm
VIII. COMMISSIONER COMMENTS and REPORTS from MEETINGS/EVENTS
INFORMATIONAL REPORTS
Informational Update on Utilities' Quarterly Financial Report for Q2 of FY2022
IX. FUTURE TOPICS FOR UPCOMING MEETING
SUPPLEMENTAL INFORMATION - The materials below are provided for informational purposes, not for
action or discussion during UAC Meetings (Govt. Code Section 54954.2(a)(3)).
12-Month Rolling Calendar Public Letter(s) to the UAC
MATERIALS RELATED TO AN ITEM ON THIS AGENDA SUBMITTED TO THE COMMISSION AFTER DISTRIBUTION OF THE AGENDA
PACKET ARE AVAILABLE FOR PUBLIC INSPECTION IN THE UTILITIES DEPARTMENT AT PALO ALTO CITY HALL, 250 HAMILTON AVE.
DURING NORMAL BUSINESS HOURS.
AMERICANS WITH DISABILITY ACT (ADA)
Persons with disabilities who require auxiliary aids or services in using City facilities, services or programs or who would like information on the
City’s compliance with the Americans with Disabilities Act (ADA) of 1990, may contact (650) 329-2550 (Voice) 24 hours in advance.
PUBLIC COMMENT INSTRUCTIONS
Members of the Public may provide public comments to teleconference meetings via email,
teleconference, or by phone.
1. Written public comments may be submitted by email to
UACPublicMeetings@CityofPaloAlto.org.
2. Spoken public comments using a computer will be accepted through the
teleconference meeting. To address the Commission, click on the link below for the
appropriate meeting to access a Zoom-based meeting. Please read the following
instructions carefully.
• You may download the Zoom client or connect to the meeting in-browser. If
using your browser, make sure you are using a current, up-to-date browser:
Chrome 30+, Firefox 27+, Microsoft Edge 12+, Safari 7+. Certain functionality
may be disabled in older browsers including Internet Explorer.
• You will be asked to enter an email address and name. We request that you
identify yourself by name as this will be visible online and will be used to notify
you that it is your turn to speak.
• When you wish to speak on an agenda item, click on “raise hand.” The Attendant
will activate and unmute speakers in turn. Speakers will be notified shortly
before they are called to speak.
• When called, please limit your remarks to the time limit allotted.
• A timer will be shown on the computer to help keep track of your comments.
3. Spoken public comments using a smart phone use the telephone number listed below.
When you wish to speak on an agenda item hit *9 on your phone so we know that you
wish to speak. You will be asked to provide your first and last name before addressing
the Council. You will be advised how long you have to speak. When called please limit
your remarks to the agenda item and time limit allotted.
Join Zoom Webinar Here
Meeting ID: 966-9129-7246
City of Palo Alto (ID # 14465)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type: IV. APPROVAL OF THE MINUTES
City of Palo Alto Page 1
Title: Approval of the Minutes of the Utilities Advisory Commission Meeting
held on May 4, 2022
From: Director of Utilities
Lead Department: Utilities
Recommended Motion
Staff recommends that the UAC consider the following motion:
Commissioner ______ moved to approve the draft minutes of the May 4, 2022 meeting
as submitted/Amended.
Commissioner ______ seconded the motion.
Attachments:
• Attachment A: Draft Minutes
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Utilities Advisory Commission Minutes Approved on: Page 1 of 9
DRAFT
UTILITIES ADVISORY COMMISSION MEETING
MINUTES OF May 4, 2022 SPECIAL MEETING
CALL TO ORDER
Chair Forssell called the meeting of the Utilities Advisory Commission (UAC) to order at 6:06 p.m.
Present: Chair Forssell, Vice Chair Segal, Commissioners Bowie, Johnston, Metz, Scharff and Smith
Absent:
AGENDA REVIEW AND REVISIONS
None.
ORAL COMMUNICATIONS
None.
APPROVAL OF THE MINUTES
Chair Forssell invited comments on the April 6, 2022 UAC draft meeting minutes.
Commissioner Smith remarked that due to a recent change to his office location, he has been biking to work
and greatly appreciated the City of Palo Alto for being a bike-safe city.
Commissioner Johnston noted on pg. 4, 3rd paragraph reads Honk should be Honker. On pg. 5, 2nd paragraph
reads traditional board should be broadband.
Council Member Cormack noted on pg. 9, 2nd paragraph reads encouraged the UAC to consider Council
should be Staff.
Commissioner Scharff moved to approve the draft minutes of the April 6, 2022 meeting as amended.
Commissioner Johnston seconded the motion.
The motion carried 6-0 with Chair Forssell, and Commissioners Bowie, Johnston, Metz,
Scharff, and Smith voting yes.
Vice Chair Segal abstain.
UNFINISHED BUSINESS
None.
UTILITIES DIRECTOR REPORT
Dean Batchelor, Utilities Director, delivered the Director's Report.
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Utilities Advisory Commission Minutes Approved on: Page 2 of 9
Earth Day Events: On Friday April 22, Utilities shared a tent with Zero Waste at Stanford Healthcare’s Earth
Day Event and interacted with doctors, nurses, and other Stanford employees who came by to play energy
and conservation games. Mayor Pat Burt also stopped by the event and gave a talk about the City’s climate
goals. Later that day, CPAU hosted a table at the “March and Rally for Earth” event in front of City Hall at
King Plaza. Speakers included Congresswoman Anna Eshoo, Assembly Member Marc Berman, and Mayor
Burt. Event attendees stopped by our table to ask about incentive programs and take home informational
material and efficiency devices.
On Saturday April 23, CPAU partnered with local non-profit Acterra to host its first e-Bike test ride event and
EV expo at Mitchell Park Community Center. Several local volunteers brought their e-Bikes to show and
answer questions, including foldable lightweight bikes, larger cargo bikes, and an e-Bike with panniers filled
with the morning’s farmers market haul. We also had three EV models on display such as the Kia EV6, Hyundai
Ioniq and Lucid Air. More than 100 people attended the event and we provided over 50 test rides. Events
hosted with Acterra have been well-attended by the community. If any of the Commissioners are involved in
neighborhood groups or communities that may be interested in hosting a Neighborhood EV Expo please let
us know! Block parties, places of worship, and schools are all possible candidates.
Upcoming Events: On May 12, from 7-8pm, discover how to maximize the convenience and effectiveness of
EV charging. Learn about buying and installing a home charger, how to find and use public chargers, charging
speeds and costs, rebates, and charging options for residents of apartments and condos. The Cities of Palo
Alto and Sunnyvale are presenting sponsors. Details at cityofpaloalto.org/workshops
Hydroelectric Update: After a promising start, it’s now clear that the 2021-2022 water year will be the third
straight very dry year for California. As of April 26th, precipitation totals in Northern and Central California
are almost 20-30% below average for this time of year (after being above average through January). Reservoir
levels remain very low too. Across Northern and Central California, most reservoirs are about 30- 50% below
their average levels for this point in time. As a result, Palo Alto’s hydroelectric projections for FY
2022 and FY 2023 are now very low—they are projected to produce around 245 this fiscal year, which is
about 52% of the long-term average level of hydro output, and 285 gigawatts per hour in FY 2023, which is
60% of the long-term average level.
Water Supply Update: As of April 4, 2022, Regional Water System storage was 74% full (normal system
storage for this time of year is 82%). The SFPUC declared a local water shortage emergency on November 23,
calling for voluntary systemwide 10% water use reductions. For January through mid-April 2022, Palo Alto’s
water usage exceeded its budget by about 18% cumulatively. Staff is planning more outreach to encourage
residents and business to save water while still caring for the urban canopy and to remind them of current
water waste restrictions. Staff expects the State Board to adopt emergency regulations in May that ban
irrigation of ornamental turf in commercial, industrial, and institutional sectors, except to ensure the health
of trees. Additionally, the emergency regulation will require Palo Alto to implement Stage 2 of the Water
Shortage Contingency Plan which will require restaurants to serve water to customers only upon request and
require hotels and motels to provide guests with the option of not having linens laundered daily.
Tree Line USA: CPAU has earned the recognition as a 2022 Tree Line USA member. Tree Line USA is a national
program recognizing public and private utilities for best practices that protect and preserve America’s urban
forests. This program is possible through a partnership with the Arbor Day Foundation and the National
Association of State Foresters. Tree Line USA promotes the coexistence of delivering safe and reliable
electricity while maintaining healthy community trees. Successfully achieving Tree Line USA standards
through training employees in quality tree-care practices, educating the public about planting trees for
energy conservation, and helping homeowners plant appropriate trees near utility lines, not only helps
provide trees for a greener future, but also yields long-term savings for customers.
EV Charger Count Update: We currently have over 130 sites enrolled in the CPAU EV programs, including
86 multi-family properties representing over 3,400 units.
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Utilities Advisory Commission Minutes Approved on: Page 3 of 9
Bachelor commented Staff made an error and sent out 11,000 notices to customers stating that their
accounts were delinquent. The notices should have been sent out to only 1,500 customers. Moving forward,
the department has discussed more checks and balances regarding communications that are sent out to the
public.
In answer to Chair Forssell’s inquiry regarding the new process for community communications, Bachelor
noted that several Staff members from customer service, Mr. Yuan and himself will review the
communications before they are distributed. In response to Chair Forssell’s question regarding the number
of delinquent customers now versus pre-pandemic times, Bachelor stated typically 20 to 30 folks fall into the
category of being 90-days late. For folks who are 90-days over, Staff has requested they contact the
department and set up a payment plan. In reply to Chair Forssell’s query regarding residential versus
commercial customers, Dave Yuan, Strategic Business Manager, shared that 1,200 customers are 180-days
past due on their payment and 1,041 were residential and 175 were commercial customers. Between 90-
days and 180-days, an additional 238 customers had an outstanding bill.
Vice Chair Segal recommended Staff not only review the communications that go out but the list of folks who
will receive the communications. In answer to her query regarding how many folks have signed up on the
Fiber Hub since the last update, Batchelor answered 10 to 15 folks have signed up since the last update. As
of today, there are 246 pins of interest.
NEW BUSINESS
ITEM 1: ACTION: Approval of UAC Chair and Vice Chair to Serve a Short Term From May 4, 2022 to March 31,
2023
Chair Forssell appreciated the Commission allowing her to Chair the Utilities Advisory Commission for the
past 2-years.
Commissioner Scharff elected Vice Chair Segal as Chair.
Vice Chair Segal accepted the nomination.
ACTION: Commissioner Scharff moved to approve Commissioner Segal as Chair.
Motion seconded by Commissioner Forssell
The motion carried 7-0 with Commissioners Bowie, Forssell, Johnston, Metz, Scharff, Segal and Smith voting
to approve Commissioner Segal as Chair.
Commissioner Scharff nominated Commissioner Johnston as Vice Chair.
Commissioner Johnston accepted the nomination.
ACTION: Commissioner Scharff moved to approve Commissioner Johnston as Vice Chair.
Motion seconded by Commissioner Forssell.
The motion carried 7-0 with Chair Segal, Commissioners Bowie, Forssell, Johnston, Metz, Scharff, and Smith
voting to approve Commissioner Johnston as Vice Chair
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Utilities Advisory Commission Minutes Approved on: Page 4 of 9
ITEM 2: ACTION: Approval of UAC Budget Subcommittee Members to Serve a Short Term of May 4, 2022 to
March 31, 2023
Commissioner Scharff volunteered.
Commissioner Smith announced he would like to be on the subcommittee.
Commissioner Bowie stated he would also like to volunteer for the subcommittee.
ACTION: Commissioner Scharff, Commissioner Smith, and Commissioner Bowie volunteered to be on the
Budget Subcommittee for a short term from May 04, 2022 to March 31, 2023.
ITEM 3: ACTION: Approval of UAC Fiber Subcommittee Members to Serve a Short Term From May 04, 2022
Through March 31, 2023
Vice Chair Johnston, Commissioner Smith and Commissioner Metz expressed interest in being on the
subcommittee.
ACTION: Vice Chair Johnston, Commissioner Smith, and Commissioner Metz volunteered to be on the Fiber
Subcommittee, for a 10-month term from May 4, 2022 through March 31, 2023.
ITEM 4: ACTION: Adoption of a Resolution Authoring the use of Teleconference for Utilities Advisory
Commission Meetings During Covid-19 State of Emergency
ACTION: Commissioner Scharff moved Staff recommendation that the Utilities Advisory Commission (UAC)
Adopt a Resolution (Attachment A) authorizing the use of teleconferencing under Government Code Section
54953(e) for meetings of the Utilities Advisory Commission (UAC) and its committees due to the Covid-19
declared state of emergency.
Seconded by Vice Chair Johnston
Motion carries 7-0 with Chair Segal, Vice Chair Johnston and Commissioners Bowie, Forssell, Metz, Scharff,
and Smith voting yes.
ITEM 5: ACTION: Staff Recommendation That the Utilities Advisory Commission Recommend the City Council
Adopt the Proposed Operating and Capital Budgets for the Utilities Department for Fiscal Year 2023
Dean Batchelor, Director of Utilities, reminded the UAC that rates have already been approved for the
Operating and Capital Budgets.
Anna Vuong, Senior Business Analyst, reported the budget was a baseline budget that maintained current
service levels. The majority of the proposals was for Staffing and one for building electrification. After the
UAC makes its recommendation, the item will move to the Finance Committee and then to the full Council in
June of 2022 for final approval. While no new Capital Projects were being proposed, several projects were
underway or planned for Fiscal Year (FY) 2023. These included the Outage Management System, Fiber
Management System and master plan studies for the Electric Distribution System as well as the Wastewater
Collection System. The rates proposed for FY 2023 resulted in a $15.48 increase on customers’ monthly bill.
In reply to Commissioner Metz’s query regarding the percentage of each bill being commodity versus non-
commodity, Dave Yuan, Strategic Business Manager, answered that the 5-year Financial Forecast Plan should
have the breakdowns for supply and distribution costs.
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Utilities Advisory Commission Minutes Approved on: Page 5 of 9
In answer to Vice Chair Johnston’s query regarding the scope of work for the Electric Distribution System,
Tomm Marshall, Assistant Director of Utilities Operations, remarked a consultant was currently identifying
what upgrades that were needed for the electrical grid as well as determining how much load increase there
will be. The study should be concluded by late summer into early fall of 2022. Vice Chair Johnston was very
pleased to hear that the project was underway and looked forward to seeing the study.
In answer to Commissioner Bowie’s query if hydro rate adjustments were included in the FY 2022 monthly
bill, Yuan answered no. For FY 2023, it depends on the hydro conditions if the adjustment is needed and
whether it will be carried forward in FY 2024.
In reply to Commissioner Forssell’s understanding that the User Tax is paid to the City’s General Fund, Yuan
confirmed that is correct.
In response to Commissioner Scharff’s inquiry regarding the increase in water rates, Yuan explained Palo Alto
will see an 8.9 percent increase due to San Francisco Public Utility Commission (SFPUC) raising rates and
distribution increases. He noted that distribution increases were driven by salaries and benefits, Capital
Improvement Projects (CIP) improvements, escalating costs and replenishing the City’s reserves. In answer
to Commissioner Scharff’s query regarding SFPUC’s rate increases being driven by the water system rebuild,
Yuan clarified the increase was mainly driven by the drought.
Vuong addressed Commissioner Metz’s question regarding commodity charges versus supply. The
commodity for the Electric Fund was 56 percent, the Gas Fund was 31 percent, Wastewater Fund was 53
percent and the Water Fund was 45 percent. Jonathan Abendschein, Assistant Director of Utilities Resource
Management, understood Commissioner Metz’s thinking was a certain overall percentage reflected a higher
percentage in just the non-commodity part of the rates if the commodity stayed the same. That was correct
and the ratios depended on the utility.
Alex Harris, Sr. Business Analyst, presented the Operating and Capital Budget for the Electric Fund. The top
three expense categories included the utility purchase, CIP, and salary and benefits. For FY 2023, there were
approximately $211.7 million in the budget and $120.82 million for full-time equivalent (FTE) positions. The
year-over-year increase for salary and benefits was $2.8 million due to staffing changes. Also, there was a
city-wide 4 percent base increase and an additional contribution to the Pension Trust Fund. Another change
was seen in contract services which had an increase of $4.8 million and was due to contract alignments for
tree line clearing and high voltage line construction and building electrification program support increases.
Overall, the FY 2023 Budget for the Electric Fund was projected to be spending slightly below budget. The
utility purchase was forecasted to exceed the budget by $2 million due to costlier on-the-spot purchases as
a result of low hydro output.
In answer to Vice Chair Johnston’s queries regarding what timeframe did the FY 2022 Budget to Actuals cover
and the definition of encumbrances, Harris answered the figures covered up to May 2, 2022 and
encumbrances meant funds that were already dedicated to contracts.
Harris remarked concerning the Electric Fund 5-year CIP Plan, the FY 2022 CIP column was higher at $35
million due to a carryover of $8.5 million from the previous year. Staff projected FY 2022 will conclude with
$12 million in actuals. The City will commit roughly $13 million to contracts for FY 2023 and then return the
remaining balance of $3 to $6 million to the fund. Staff presented a table with the electric historical project
actuals.
In answer to Commissioner Forssell’s inquiries regarding the Foothills Rebuild Project, Harris explained the
$530,000 was an error made by Staff and represented labor and materials that should not have been included
in the project cost. Yuan confirmed the project started in the year 2020 and included a total of 11 miles of
lines that were being undergrounded. The 5-year CIP of $11 million was to cover the remaining 9.5-miles of
the project. The plan predicted the City can only do roughly $2 million worth in one year.
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Utilities Advisory Commission Minutes Approved on: Page 6 of 9
In answer to Commissioner Metz’s inquiry regarding the 5-year CIP not including work for the Sustainability
and Climate Action Plan (S/CAP), Yuan confirmed that is correct, but Staff had discussed including those
projects for FY 2024.
In reply to Chair Segal’s query regarding money spent on smart grid technology, Yuan answered
approximately $100,000 had been spent but the project was delayed due to a delay in delivery of the meters.
Staff predicted 3,000 meters will be installed in FY 2023 with the remaining being installed in FY 2024. In
answer to Chair Segal’s inquiry regarding the rebuild of Underground 15 and discussion with the
neighborhood, Batchelor confirmed Staff provided the neighborhood with several options. The
neighborhood did not support the City installing transformers and so the City’s Legal Department took over
discussions.
Council Member Cormack reiterated the projections in the Electric 5-year CIP 2023-2027 chart did not include
funding for the electrical grid modernizing project. She encouraged Staff to make that statement clear during
the presentation to Finance Committee. She appreciated the electric historical project actuals chart.
Harris presented the Gas Fund and noted the top three expenses were the utility purchase, CIP and salary
and benefits. For FY 2023, $58.6 million was budgeted in the Gas Fund with 54.56 FTEs. The year-over-year
comparison showed that salary and benefits had increased by $0.9 million. The general expense and the
contract service category increased due to the $2.1 million for building electrification programs. The CIP
showed a $5.7 million increase due to FY 2023 being a gas main construction year for the fund. The Gas
Operating Expenses FY 2022 Budget to Actuals showed the budget was trending on track. With respect to the
Gas Fund 5-year CIP Forecast for FY 2023 through FY 2027, Staff anticipated that FY 2022 will end with $7
million year-to-date actuals, $2 million encumbrances and roughly $2 million to be re-appropriated. Staff
included in the report the gas historical project actuals which included many of the non-recurring one-time
gas main replacement projects.
In answer to Chair Segal’s query regarding the $3.5 million for the first-year budget for Project 23, Yuan
confirmed the $3.5 million was the original cost estimate but Staff made an error and used outdated
construction costs. Moving forward, any future main replacements will cost between $7 and $8 million.
In reply to Commissioner Forssell’s request about where to find gas main replacements after the year 2016,
Yuan noted the information was in the Gas 5-year CIP 2023-2027 on page 87 of the capital packet.
Yuan presented the Fiber Fund and remarked the total budget for the fund was $4.6 million. The biggest
change to the cost drivers in FY 2023 was the CIP. Approximately $1.2 million was encumbered with Magellan,
$0.3 million was set aside for the undergrounding project in the Foothills and $1 million was set aside for the
rebuild of the fiber network. With respect to the Fiber Operating Expenses FY 2022 Budget to Actuals, many
of the items were on target except for salary and benefits. Staff proposed to reclassify one vacant position in
the Fiber Fund to the Electric Fund. Regarding the Palo Alto Fiber project, $2.4 million was awarded to the
Magellan contract and the year-to-date expenditure was $1.2 million. With respect to the Fiber 5-year CIP
2023- 2027, the majority of the funds in FY 2022 were for the Magellan contract.
In reply to Chair Segal’s query regarding residents on Page Mill receiving fiber to the premises (FTTP) with the
Foothills Underground Project, Yuan explained while the lines are being undergrounded, extra fiber conduit
will be installed.
Yuan presented the Wastewater Collection Fund and shared the budget total was $23.5 million with 29 FTEs.
The largest cost driver was the utility purchase or wastewater treatment charges at 51 percent of the total
budget.
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Utilities Advisory Commission Minutes Approved on: Page 7 of 9
In answer to Chair Segal’s query regarding the desalinization plant, Yuan confirmed that the plant was not
under the utility but some of the cost was passed through via treatment charges.
Council Member Cormack clarified it was not technically a desalinization plant but rather a salt removal
facility. Chair Segal acknowledged the comments that the level of salt was too high and wondered where
that was reflected. Council Member Cormack believed that question was for Public Works.
Yuan continued to the Wastewater Operating Expenses FY 2022 Budget to Actuals and announced all budget
categories were on track except salary and benefits and the CIP. The Wastewater 5-year CIP 2023-2027 Plan
continued with alternating years for construction. FY 2022 included $4 million that will be re-appropriated to
FY 2023 for a construction project. Staff will be returning to the UAC to discuss accelerating the sewer
replacement projects in the fall of 2022. Staff shared the wastewater historical project actuals chart with the
UAC. He moved to the Water Fund and shared the total FY 2023 Proposed Budget was $59 million with 48
FTEs. Year-over-year, purchase cost was increasing by 2 percent, but CIP was decreasing because FY 2023
was a non-construction year. Staff included one-time CIP projects for FY 2023, including security for the water
tanks and purchasing emergency generators for wildfire mitigation. With respect to Water Operating
Expenses FY 2022 Budget to Actuals, there was a decrease in rent and debt service due to $1 million being
set aside for emergency water generators. With respect to the Water 5-year CIP 2023-2027, the Park
reservoir replacement or rehabilitation will begin in FY 2023 and FY 2022 included the completion of the
Corte Madera reservoir. With respect to the water historical project actuals, Staff predicted the water tank
upgrades will be completed at end of year 2028.
In reply to Commissioner Forssell’s inquiry regarding the total actuals compared to the budget, Yuan
confirmed Staff can include another column in the project actual table that compared the proposed budget
to how much was spent. For the Electric Fund, every year the approved budget was approximately $25 million
and roughly $10 is spent. In answer to Chair Forssell’s inquiry regarding why the budget for the Electric Fund
did not match expenditures, Yuan explained the remaining amount was in encumbrances as well as projects
that were planned for but never started. Also, approximately $5 to $7 million was rolled over from the prior
year’s budget. The Water, Wastewater and Gas Fund did not have such a significant delta between actuals
and total budget. In answer to Chair Forssell’s query regarding if the City was falling behind the pace of CIPs
that needed to happen, Yuan explained Staff reviewed all the projects for the Electric Fund and
disencumbered $6 million and those were returned to the reserves. Marshall agreed the City was behind on
electric projects but that was due to Staffing issues. Staff was working on hiring more consultants to move
projects along at a quicker pace.
Vice Chair Johnston remarked he was struggling with the City approving a budget when the funds are not all
spent for that specific year. In answer to his question regarding setting the rates based to cover the full
amount of capital expenditures budgeted, Abendschein stated the rates are based on historical spend levels
and are adjusted for one-time CIPs. In response to Vice Chair Johnston’s understanding unspent funds are
placed in the reserves, Abendschein confirmed that is correct and noted that rates are decreased if the
reserve goes beyond the maximum guideline level.
Yuan noted the City awards the full amount for contracts, even if the contract spans over 2- to 3-years. Chair
Forssell commented those funds were not the issue. The issue was funding projects that never come to
fruition and that was the data she wanted to be quantified.
In response to Chair Segal’s query regarding if the rates included inflationary increases, Batchelor confirmed
inflationary increases are included in contract budgets.
Council Member Cormack commented the problem of having a higher budget that does not get fully spent
was a problem across the entire City. She encouraged the UAC to focus on the question of does the work that
is being done makes sense based on the longevity of the equipment. She assured the UAC that the Finance
Committees spends a significant amount of time making sure the numbers match up.
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Commissioner Forssell confirmed her comments were focused on making sure the infrastructure is
maintained in a healthy state.
Commissioner Metz stated he was impressed with the level of detail in the Capital and Operating Budget. He
highlighted that both budgets show how old the systems are and the UAC should focus on how to address
that matter.
Chair Segal remarked she was sensitive to delaying projects because the more delayed a project is, the more
the cost for that project increases and that impacted customer rates. She supported hiring more contract
workers to make sure projects are completed promptly. She circled back to recycled water and referenced a
sentence in the Staff report that landscape folks were concerned about using the water. In reply to her
question regarding how the water was being used, Council Member Cormack remarked the quality of the
City’s recycled water was sufficient for many uses but was not sufficient for salt-sensitive species. Batchelor
mentioned Staff will be presenting the Water One Plan to the UAC later in the year. Karla Dailey, Acting
Assistant Director of Utilities Resource Management, confirmed that water quality was a larger problem for
the City of Mountain View than Palo Alto. The recycled water system could not be expanded in Palo Alto
without improving the quality.
Vuong presented current Staffing positions and noted there were 45 vacant positions within the department.
There were 25 active recruitments and that included positions added at the mid-year budget. Batchelor noted
recently the electric engineering manager left the City for a General Manager position in a different city and
that impacted the electric engineering division. Vuong continued and confirmed that through natural
attrition, the City was losing more employees than hiring. To address Staffing impacts, the department
implemented recruitment and retainment strategies. One strategy was to reorganize the engineering and
operations into two groups; Electric and Fiber; and Water, Gas, and Wastewater Collection. This effort had
helped reach more qualified candidates. For the FY 2023 Budget, Staff requested a net add of 5.5 regular FTE
and 2.6 hourly FTEs.
In answer to Commissioner Metz’s inquiry regarding why the City was not able to retain Staff, Batchelor
believed it was salary competition and the cost of living in Palo Alto.
In reply to Commissioner Forssell’s query regarding requests for proposals (RFP), Yuan commented the
market was very competitive and CIP projects usually receive two or three bids. If no bids are received, Staff
has to rescope the RFP and/or contact construction firms and inquire why they did not bid on the project. In
answer to Commissioner Forssell’s question regarding how many companies can handle the City’s larger
projects, Batchelor answered three to four. Marshall noted it was a very competitive market for electric
construction Staff and it was very difficult to find contractors. Also, Palo Alto has many constraints that cost
construction companies more money and make it difficult to work in the city. In answer to Commissioner
Forssell’s assumption that Council was aware of the constraints, Council Member Cormack answered yes.
Commissioner Forssell invited the budget subcommittee to share their insights. Commissioner Scharff
commented he had no additional thoughts other than he agreed with Council Member Cormack that the UAC
should focus on does the work being done on infrastructure make sense based on the longevity of the
equipment. Commissioner Smith believed the UAC never addressed construction hours and the permitting
process because another City Committees manage it. He acknowledged it was a huge problem that many
contracting companies did not want to work in the City. With respect to Staffing challenges, he agreed the
three main changes to recruit Staff was the market was very competitive in terms of salary and the cost of
living was very high.
Council Member Cormack believed the City was coming to a critical point regarding vacant Staff positions in
the electrical engineering division. She wanted to better understand the strategy of employee and subsidized
housing. Batchelor reiterated housing in the City was a real concern for many current and past Staff. In
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answer to Council Member Cormack’s question regarding if Staff wanted to relocate their families to Palo
Alto, Batchelor predicted many would rather live in Palo Alto or live within 30-minutes of Palo Alto. He noted
Pacific Gas and Electric (PG&E) did give a subsidy for folks living on the peninsula. Council Member Cormack
was interested in understanding what the impacts to rates would be if the City hired more electrical
engineering and operation Staff.
Commissioner Scharff believed the City should pay its Staff more than the City of Santa Clara. With respect
to housing, he suggested the City buy an apartment complex for folks to rent as well as implement an equity
sharing program. The main focus should be to evaluate the different impediments and address folks' needs.
He stated part of the problem was how to address the vacancies in the Utility Department as part of the
whole City but also somewhat separately.
Commissioner Smith echoed Commissioner Scharff’s comment that Palo Alto should have higher salaries and
that the problem was larger than just the Utilities Department. He found the apartment complex concept a
great idea. He commented that while Design-Build, project delivery system, is expensive, it does incentivize
contractors to participate. He believed the City could manage the risk by providing specific targets in terms
of Design-Build opportunities. He suggested having a focus group made up of members from several City
Commissions, Committees and Boards to discuss constraints such as working hours and the permitting
process.
Commissioner Bowie echoed many of the points already stated. He believed an ad hoc committee that
focused on recruitment and retainment of Staff would be beneficial and Chair Segal agreed.
ACTION: Staff recommends the Utilities Advisory Commission recommended the City Council adopt the
Proposed Operating Budgets for the Utilities Department for Fiscal Year 2023. Staff recommends the Utilities
Advisory Commission recommended the City Council adopt the Proposed Capital Budgets for the Utilities
Department for Fiscal Year 2023.
Commissioner Scharff moved Staff recommendation
Commissioner Forssell seconded the motion
Motion carried 7-0 with Chair Segal, Vice Chair Johnston and Commissioners Bowie, Forssell, Metz, Scharff,
and Smith voting yes
COMMISSIONER COMMENTS and REPORTS from MEETINGS/EVENTS
None.
FUTURE TOPICS FOR UPCOMING MEETINGS: June 01, 2022
Chair Segal requested an informational report on the Cross-Bore Project.
NEXT SCHEDULED MEETING: June 01, 2022
Commissioner Forssell moved to adjourn. Vice Chair Johnston seconded the motion. The motion carried 7-0
with Chair Segal, Vice Chair Johnston, and Commissioners Bowie, Forssell, Metz, Scharff, and Smith voting
yes.
Meeting adjourned at 8:35 p.m.
Respectfully Submitted
Tabatha Boatwright
City of Palo Alto Utilities
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City of Palo Alto (ID # 14429)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type: VII. NEW BUSINESS
City of Palo Alto Page 1
Title: Adoption of a Resolution Authorizing Use of Teleconferencing for
Utilities Advisory Commission Meetings During Covid -19 State of Emergency
From: Director of Utilities
Lead Department: Utilities
Recommendation
Adopt a Resolution (Attachment A) authorizing the use of teleconferencing under Government
Code Section 54953(e) for meetings of the Utilities Advisory Commission (UAC) and its
committees due to the Covid-19 declared state of emergency.
Background
In February and March 2020, the state and the County declared a state of emergency due to
the Covid-19 pandemic. Both emergency declarations remain in effect.
On September 16, 2021, the Governor signed AB 361, a bill that amends the Brown Act,
effective October 1, 2021, to allow local policy bodies to continue to meet by
teleconferencing during a state of emergency without complying with restrictions in State
law that would otherwise apply, provided that the policy bodies make certain findings at
least once every 30 days.
AB 361, codified at California Government Code Section 54953(e), empowers local policy bodies
to convene by teleconferencing technology during a proclaimed state of emergency under the
State Emergency Services Act in any of the following circumstances:
(A) The legislative body holds a meeting during a proclaimed state of emergency, and
state or local officials have imposed or recommended measures to promote social
distancing.
(B) The legislative body holds a meeting during a proclaimed state of emergency for the
purpose of determining, by majority vote, whether as a result of the emergency,
meeting in person would present imminent risks to the health or safety of
attendees.
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(C) The legislative body holds a meeting during a proclaimed state of emergency and has
determined, by majority vote, pursuant to subparagraph (B) (B), that, as a result of
the emergency, meeting in person would present imminent risks to the health or
safety of attendees. (Gov. Code § 54953(e)(1).)
In addition, Section 54953(e)(3) requires that policy bodies using teleconferencing reconsider
the state of emergency within 30 days of the first teleconferenced meeting after October 1,
2021, and at least every 30 days thereafter, and find that one of the following circumstances
exists:
1. The state of emergency continues to directly impact the ability of the
members to meet safely in person.
2. State or local officials continue to impose or recommend measures to
promote social distancing.
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Discussion
At this time, the circumstances in Section 54953(e)( 1)(A) exist. The Santa Clara County Health
Officer continues to recommend measures to promote outdoor activ ity, physical distancing and
other social distancing measures, such as masking, in certain contexts. (See August 2, 2021
Order.) In addition, the California Department of Industrial Relations Division of Occupational
Safety and Health (Cal/OSHA) has promulgated Section 3205 of Title 8 of the California Code of
Regulations, which requires most employers in California, including in the City, t o train and
instruct employees about measures that can decrease the spread of COVID -19, including
physical distancing and other social distancing measures.
Accordingly, Section 54953(e)(1)(A) authorizes the City to continue using teleconferencing for
public meetings of its policy bodies, provided that any and all members of the public who wish
to address the body or its committees have an opportunity to do so, and that the statutory and
constitutional rights of parties and the members of the public attend ing the meeting via
teleconferencing are protected.
To comply with public health directives and promote public safety, Palo Alto policy bodies
have been meeting via teleconference since March 2020. On September 27, 2021, the City
Council considered the format for future Council, committee, and Board and Commission
meetings. Council determined that beginning November 1, 2021, Council meetings would be
conducted using a hybrid format that allows Council Members and the public to decide
whether to attend in person, following masking and distancing protocols, or participate via
teleconference. Council directed that Council standing and ad-hoc committees and Boards
and Commissions would continue meeting via teleconference through March 2022.
Adoption of the Resolution at Attachment A will make the findings required by Section
54953(e)(3) to allow the continued use of teleconferencing for meetings of the Utilities
Advisory Commission (UAC) and its committees.
Attachments:
• Attachment A: Resolution
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NOT YET APPROVED
Resolution No. ____
Resolution Making Findings to Allow Teleconferenced Meetings Under California Government
Code Section 54953(e)
R E C I T A L S
A. California Government Code Section 54953(e) empowers local policy bodies to convene by
teleconferencing technology during a proclaimed state of emergency under the State Emergency
Services Act so long as certain conditions are met; and
B. In March 2020, the Governor of the State of California proclaimed a state of emergency
in California in connection with the Coronavirus Disease 2019 (“COVID-19”) pandemic, and that state
of emergency remains in effect; and
C. In February 2020, the Santa Clara County Director of Emergency Services and the
Santa Clara County Health Officer declared a local emergency, which declarations were
subsequently ratified and extended by the Santa Clara County Board of Supervisors, and those
declarations also remain in effect; and
D. On September 16, 2021, the Governor signed AB 361, a bill that amends the Brown Act
to allow local policy bodies to continue to meet by teleconferencing during a state of emergency
without complying with restrictions in State law that would otherwise apply, provided that the
policy bodies make certain findings at least once every 30 days; and
E. While federal, State, and local health officials emphasize the critical importance of
vaccination and consistent mask-wearing to prevent the spread of COVID-19, the Santa Clara County
Health Officer has issued at least one order, on August 2, 2021 (available online at here), that continues
to recommend measures to promote outdoor activity, physical distancing and other social distancing
measures, such as masking, in certain contexts; and
F. The California Department of Industrial Relations Division of Occupational Safety and
Health (“Cal/OSHA”) has promulgated Section 3205 of Title 8 of the California Code of Regulations,
which requires most employers in California, including in the City, to train and instruct employees
about measures that can decrease the spread of COVID-19, including physical distancing and other
social distancing measures; and
G. The Utilities Advisory Commission has met remotely during the COVID-19 pandemic and
can continue to do so in a manner that allows public participation and transparency while minimizing
health risks to members, staff, and the public that would be present with in-person meetings while
this emergency continues; now, therefore,
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The Utilities Advisory Commission RESOLVES as follows:
1. As described above, the State of California remains in a state of emergency due to the
COVID-19 pandemic. At this meeting, the Utilities Advisory Commission has considered the
circumstances of the state of emergency.
2. As described above, State and County officials continue to recommend measures
to promote physical distancing and other social distancing measures, in some
settings.
AND BE IT FURTHER RESOLVED, That for at least the next 30 days, meetings of the Utilities Advisory
Commission and its committees will occur using teleconferencing technology. Such meetings of the
Utilities Advisory Commission and its committees that occur using teleconferencing technology will
provide an opportunity for any and all members of the public who wish to address the body and its
committees and will otherwise occur in a manner that protects the statutory and constitutional rights
of parties and the members of the public attending the meeting via teleconferencing; and, be it
FURTHER RESOLVED, That the Utilities Advisory Commission staff liaison is directed to place a resolution
substantially similar to this resolution on the agenda of a future meeting of the Utilities Advisory
Commission within the next 30 days. If the Utilities Advisory Commission does not meet within the next
30 days, the staff liaison is directed to place a such resolution on the agenda of the immediately following
meeting of the Utilities Advisory Commission.
INTRODUCED AND PASSED:
AYES:
NOES:
ABSENT:
ABSTENTIONS:
ATTEST:
Staff Liaison Chair of Utilities Advisory Commission
APPROVED AS TO FORM: APPROVED:
City Attorney Department Head
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City of Palo Alto (ID # 14159)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type:
City of Palo Alto Page 1
Title: Staff Recommends That the Utilities Advisory Commission Recommend
the City Council Adopt the 2022 Annual Water Shortage Assessment Report
From: Director of Utilities
Lead Department: Utilities
REQUEST
Staff requests the Utilities Advisory Commission (UAC) recommend the City Council adopt the 2022
Annual Water Shortage Assessment Report.
EXECUTIVE SUMMARY
Beginning in 2022, every urban water supplier in California must conduct an Annual Water Supply and
Demand Assessment as required by California Water Code Section 10632 (a). Each urban water supplier
must also submit an Annual Water Shortage Assessment Report to the Department of Water Resources
(DWR) on or before July 1, as required by California Water Code Section 10632.1. The City’s Annual
Water Shortage Assessment Report (Tables 1-5 below) shows that planned water conservation actions
are anticipated to adequately address anticipated potable water supply shortages.
DWR will prepare a summary report on its review of the Annual Water Supply and Demand Assessment
results and provide it to the State Water Resources Control Board (State Board) by September 30 each
year. The DWR report will include water shortage information at the supplier level, as well as regional
and statewide analysis of water conditions as required by California Water Code Section 10644 (c)(1)(B).
DISCUSSION
To prepare the 2022 Annual Water Shortage Assessment Report, staff followed the procedures outlined
in its Water Shortage Contingency Plan, contained in Section 7 of the City’s 2020 UWMP. Palo Alto’s
2022 Annual Water Shortage Assessment Report uses the DWR-developed Optional Annual Assessment
Tool format. This format includes the 5 tables shown below. Staff will submit the standard tables to
DWR by July 1, 2022. “Table 1. Annual Assessment Information” (Table 1) provides required overview
information. The remaining tables project water supply and demand for FY 2023 under continuing dry
conditions, and identify shortages and actions to meet those shortages described in more detail below.
Potable Water
Palo Alto receives 100% of its potable water supply from the San Francisco Public Utilities Commission
(SFPUC) Regional Water System. “Table 2: Water Demands” (Table 2) provides a demand projection for
each month of FY 2023 while “Table 3: Water Supplies” (Table 3) provides a supply projection equal to
the voluntary monthly water budgets SFPUC provided to Palo Alto. “Table 4(P): Potable Water Shortage
Assessment” (Table 4(P)) compares projected FY 2023 demand with supply and finds that there is a
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projected shortage of 7%, or a total of 721 Acre Feet (AF), for FY 2023. This means Palo Alto is projected
to remain in Stage 1 of the Water Shortage Contingency Plan (WSCP) for cutbacks up to 10% under the
assumed dry conditions. “Table 5: Planned Water Shortage Response Actions” (Table 5) lists the demand
reduction actions Palo Alto has implemented and plans to continue to implement throughout FY 2023.
Staff estimates Palo Alto will be able to meet the shortage with the planned demand reduction actions.
Table 5 shows the planned demand reduction actions listed using the required standard drop-down
menus. Table 4(P) shows the water use reductions associated with the Table 5 demand reduction
actions, bringing the revised shortage projection to 0% in each month of FY 2023.
Palo Alto has implemented action plans in past droughts, and during each one Palo Alto residents and
businesses have collectively responded to the call for water conservation. In the recent drought of
2015-2017, Palo Alto responded to state-mandated potable water use restrictions by implementing the
water restrictions in Stage II of its WSCP. While it is not possible to determine how much of the water
conserved can be attributed to each of the specific water use reduction actions/measures imposed, the
City exceeded the 24% cumulative reduction target for the June 1, 2015 through May 31, 2016
compliance period compared to calendar year 2013. To provide the estimates in Table 5, staff used
professional judgment to develop the best available estimates showing that the implementation of the
planned demand reduction actions will reduce demand enough to meet available supply.
Council implemented the actions shown in Table 5 through the permanent water use restrictions
outlined in the Palo Alto Municipal Code Section 12.32.010 and in Stage 1 of the Water Shortage
Contingency Plan (see Council Resolution 10022, March 7, 2022). On March 28, 2022, Governor
Newsom issued Executive Order N-7-22 requiring the State Board to consider adopting emergency
regulations by May 25, 2022 that require additional actions from urban retail water suppliers. Staff
anticipates those additional actions will include requirements for urban water suppliers to submit to the
Department of Water Resources a preliminary Annual Water Supply and Demand Assessment no later
than June 1, 2022 and to implement Stage II of their Water Shortage Contingency Plans and implement,
at a minimum, the demand reduction actions associated with a water shortage level of up to 20%. For
Palo Alto, the additional water use restrictions in Stage II of Palo Alto’s Amended 2020 WSCP are:
1) Restaurants and other food service operations shall serve water to customers only upon
request.
2) Operators of hotels and motels shall provide guests with the option of choosing not to have
towels and linens laundered daily. The hotel or motel shall prominently display notice of this
option in each guestroom using clear and easily understood language.
Staff plans to submit a working draft of the Annual Water Supply and Demand Assessment to the
Department of Water Resources on or before June 1, 2022. Staff plans to submit a recommendat ion to
the City Council to implement Stage II of Palo Alto’s Amended 2020 Water Shortage Contingency Plan.
Additionally, Santa Clara Valley Water District’s Board called to restrict ornamental landscape and lawn
irrigation with potable water to no more than two days per week.1 Staff plans to recommend to Council
to restrict irrigation of ornamental landscape and lawn with potable water to two-days per week in Palo
Alto, except as it may be required to ensure the health of trees and other perennial non-turf plantings. It
is important to maintain the health of the urban canopy in Palo Alto because trees have numerous social
and environmental benefits. For this reason, watering of ornamental landscapes or lawns where
1 Resolution Amending Resolution No. 21-68 Rescinding Resolution 17-43, Declaring a Water Shortage Emergency
Condition Calling for Water Use Restrictions, and Urging the County of Santa Clara to Proclaim a Local Emergency.
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irrigation benefits the health of trees and other perennial non-turf plantings will be specifically excluded
from staff’s proposed two-day per week irrigation restriction. Table 5 includes staff’s draft proposed
water use restrictions. Once the State Board finalizes its emergency regulations, staff will return to
Council if needed, with recommendations for implementing the required additional actions.
Non-Potable Water
For non-potable recycled water, Table 2 provides the demand projection and Table 3 notes that there is
sufficient supply to meet Palo Alto’s non-potable recycled water demand. For that reason, the supply is
set to equal demand and there is no shortage of non-potable water projected in Table 4(NP), “Non
Potable Water Shortage Assessment”.
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Table 1. Annual Assessment Information
Annual Assessment Information (Required)
Year Covered By This Shortage Report
Start: July 1,2022
End: June 30,2023
Supplier's Annual Assessment Planning Cycle
Start Month:July
End Month:June
Data Reporting Interval Used: MONTHLY
Volume Unit for Reported Supply and Demand:
(Must use the same unit throughout)AF
Water Supplier's Contact Information
Water Supplier's Name:City of Palo Alto
Contact Name:Lisa Bilir
Contact Title:Acting Senior Resource Planner
Street Address:250 Hamilton Avenue, Palo Alto
ZIP Code:94301
Phone Number:(650)329-2543
Email Address:lisa.bilir@cityofpaloalto.org
Report Preparer's Contact Information
(if different from above)
Preparer's Organization Name:
Preparer's Contact Name:
Phone Number:
Email Address:
Supplier's Water Shortage Contingency Plan
WSCP Title 2020 Water Shortage Contingency Plan of the City of Palo Alto
WSCP Adoption Date 6/7/2021
Other Annual Assessment Related Activities
(Optional)
Activity Timeline/ Outcomes / Links / Notes
Annual Assessment/ Shortage Report Title:Optional
Annual Assessment / Shortage Report Approval Date:6/13/2022
Other Annual Assessment Related Activities:
The 2020 Water Shortage Contingency Plan of the City of Palo Alto
states that Palo Alto will utilize the BAWSCA Regional Reliability
Model to evaluate water supply availability, however, the plan also
permits the City to use SFPUC data since SFPUC is the City's sole
supplier. Specifically, the 2020 Water Shortage Contingency Plan
states: "Because Palo Alto relies on only one potable water supply
source, SFPUC RWS water, the Annual Assessment will rely on key
data inputs from the SFPUC." Palo Alto determined the best data to
use for water supply is the monthly water budgets provided by
SFPUC.
(Add rows as needed)
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= From prior tables
= Auto calculated
Use Type Start Year:2022 Volumetric Unit Used 2:AF
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Total by Water
Demand Type
All Demands 1213 1105 1063 1031 810 689 648 534 650 855 1097 1080 10776
0
0
0
0
0
0
0
0
0
1213 1105 1063 1031 810 689 648 534 650 855 1097 1080 10776
All Demands Tertiary 54 53 35 22 11 2 2 11 9 24 42 50 315
0
0
0
0
54 53 35 22 11 2 2 11 9 24 42 50 315
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Total
0
0
0
0
Table 2: Water Demands 1
Projected Water Demands - Volume 3
Total by Month (Non-Potable)
1 Projections are based on best available data at time of submitting the report and actual demand volumes could be different due to many factors.
2 Units of measure (AF, CCF, MG) must remain consistent.
3 When opting to provide other than monthly volumes (bi-monthly, quarterly, or annual), please see directions on entering data for Projected Water Demand in the Table Instructions.
Notes: Potable unconstrained customer demand determined using the end-use model described in the 2020 UWMP Section 4. Non-potable unconstrained customer demand determined
based on 2020 UWMP projection.
Total by Month (Potable)
Additional
Description
(as needed)
Level of
Treatment
for Non-
Potable
Supplies
Drop-down
list
Drop-down list
May select each use multiple times
These are the only Use Types that
will be recognized by the WUEdata
online submittal tool
(Add additional rows as needed)
Demands Served by Potable Supplies
Demands Served by Non-Potable Supplies
Three years ago total demand
Four years ago total demand
Optional (for comparison purposes)
Last year's total demand
Two years ago total demand
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= From prior tables
= Auto calculated
Water Supply Start Year:2022 Volumetric Unit Used 2:AF
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun
Total by
Water
Supply Type
Purchased/Imported Water
San Francisco
Public
Utilities
Commission
Regional
Water
Supply
System
1132 1031 992 962 756 643 605 498 606 798 1023 1007 10054
0
0
0
0
0
0
0
0
0
1132 1031 992 962 756 643 605 498 606 798 1023 1007 10054 0
Recycled Water
Recycled
Water from
the Regional
Water
Quality
Control Plant
54 53 35 22 11 2 2 11 9 24 42 50 315
0
0
0
0
54 53 35 22 11 2 2 11 9 24 42 50 315 0
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Total
0
Table 3: Water Supplies 1
Projected Water Supplies - Volume 3
Water
Quality
Drop-down
List
Total Right
or Safe
Yield*
(optional)
Additional
Detail on
Water
Supply
Drop-down List
May use each category multiple
times.These are the only water
supply categories that will be
recognized by the WUEdata
online submittal tool
(Add additional rows as needed)
Potable Supplies
Non-Potable Supplies
eAR Reported Total Water Supplies
Optional (for comparison purposes)
1 Projections are based on best available data at time of submitting the report and actual supply volumes could be different due to many factors.
2 Units of measure (AF, CCF, MG) must remain consistent.
3 When opting to provide other than monthly volumes (bi-monthly, quarterly, or annual), please see directions on entering data for Projected Water Supplies in the Table Instructions.
Notes: Palo Alto purchases 100% of its potable water from SFPUC; SFPUC declared a water shortage emergency on November 23, 2021 and provided Palo Alto with voluntary monthly water
budgets. Palo Alto supplies recycled water for irrigation of the municipal golf course, a park and some other minor applications; there is sufficient supply of recycled water to meet demand.
Total by Month (Potable)
Total by Month (Non-Potable)
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= Auto calculated
= For manual input
Table 4(P): Potable Water Shortage Assessment 1 Start Year:2022 Volumetric Unit Used 2:AF
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun3 Total
Anticipated Unconstrained Demand 1,213 1,105 1,063 1,031 810 689 648 534 650 855 1,097 1,080 10,776
Anticipated Total Water Supply 1,132 1,031 992 962 756 643 605 498 606 798 1,023 1,007 10,054
Surplus/Shortage w/o WSCP Action -81 -74 -71 -69 -54 -46 -43 -36 -43 -57 -73 -72 -721
% Surplus/Shortage w/o WSCP Action -7%-7%-7%-7%-7%-7%-7%-7%-7%-7%-7%-7%-7%
State Standard Shortage Level 1 1 1 1 1 1 1 1 1 1 1 1 1
Benefit from WSCP: Supply Augmentation 0.0
Benefit from WSCP: Demand Reduction 81 74 71 69 54 46 43 36 44 57 73 72 722
Revised Surplus/Shortage with WSCP 0 0 0 0 0 0 0 0 0 0 0 0 1
% Revised Surplus/Shortage with WSCP 0%0%0%0%0%0%0%0%0%0%0%0%0%
= Auto calculated
= For manual input
Table 4(NP): Non-Potable Water Shortage Assessment 1 Start Year:2022 Volumetric Unit Used 2:AF
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun3 Total
Anticipated Unconstrained Demand: Non-Potable 54 53 35 22 11 2 2 11 9 24 42 50 315
Anticipated Total Water Supply: Non-Potable 54 53 35 22 11 2 2 11 9 24 42 50 315
Surplus/Shortage w/o WSCP Action: Non-Potable 0 0 0 0 0 0 0 0 0 0 0 0 0
% Surplus/Shortage w/o WSCP Action: Non-Potable 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%
Benefit from WSCP: Supply Augmentation 0.0
Benefit from WSCP: Demand Reduction 0.0
Revised Surplus/Shortage with WSCP 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0
% Revised Surplus/Shortage with WSCP 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%
= From prior tables
Planned WSCP Actions
1 Assessments are based on best available data at time of submitting the report and actual volumes could be different due to many factors.
2 Units of measure (AF, CCF, MG) must remain consistent.
3 When optional monthly volumes aren't provided, verify Tables 2 and 3 use the same columns for data entry and are reflected properly in Table 4 and make sure to use those same
columns to enter the benefits from Planned WSCP Actions. Please see directions on the shortage balancing exercise in the Table Instructions. If a shortage is projected, the supplier is
highly recommended to perform a monthly analysis to more accurately identify the time of shortage.
= From prior tables
Planned WSCP Actions
1 Assessments are based on best available data at time of submitting the report and actual volumes could be different due to many factors.
2 Units of measure (AF, CCF, MG) must remain consistent.
3 When optional monthly volumes aren't provided, verify Tables 2 and 3 use the same columns for data entry and are reflected properly in Table 4 and make sure to use those same
columns to enter the benefits from Planned WSCP Actions. Please see directions on the shortage balancing exercise in the Table Instructions. If a shortage is projected, the supplier is
highly recommended to perform a monthly analysis to more accurately identify the time of shortage.
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July 1,2022 to June 30,2023
Enter Amount
(Drop-down
List)
Select % or
Volume Unit
Start Month End Month
1 Expand Public Information Campaign Yes 135 AF July June
1 Offer Water Use Surveys Yes 32 AF July June
1 Provide Rebates on Plumbing Fixtures
and Devices Yes 32 AF July June
1 Provide Rebates for Landscape
Irrigation Efficiency Yes 32 AF July June
1 Provide Rebates for Turf Replacement Yes 32 AF July June
1 Landscape - Restrict or prohibit runoff
from landscape irrigation Yes 17 AF July June
1 Landscape - Limit landscape irrigation
to specific times Yes 17 AF July June
1 Landscape - Prohibit certain types of
landscape irrigation Yes 32 AF July June
1 Landscape - Other landscape restriction
or prohibition Yes 32 AF July June
1 CII - Other CII restriction or prohibition Yes 65 AF July June
1
Water Features - Restrict water use for
decorative water features, such as
fountains
Yes 17 AF July June
1
Other - Customers must repair leaks,
breaks, and malfunctions in a timely
manner
Yes 17 AF July June
1 Other - Require automatic shut of hoses Yes 17 AF July June
1 Other - Prohibit use of potable water for
construction and dust control Yes 17 AF July June
1 Other - Prohibit use of potable water for
washing hard surfaces Yes 32 AF July June
2 CII - Lodging establishment must offer
opt out of linen service No 45 AF July June
2 CII - Restaurants may only serve water
upon request No 45 AF July June
2 Landscape - Limit landscape irrigation
to specific days No 135 AF July June
Table 5: Planned Water Shortage Response Actions
NOTES: Table 5 shows the actions that Palo Alto plans to take based on the supply and demand assessment and that Palo Alto staff plan
to recommend to the Palo Alto City Council as a result of Executive Order N-7-22 emergency regulations; Palo Alto has 8 permanent
water use restrictions in the Palo Alto Municipal Code Section 12.32.010
https://codelibrary.amlegal.com/codes/paloalto/latest/paloalto_ca/0-0-0-69362#JD_Chapter12.32; Palo Alto's Amended Water Shortage
Contingency Plan, as revised 3/7/22, Stage I, outlines 7 additional demand reduction actions. Palo Alto City Council implemented the
Stage I actions on 3/7/22. Palo Alto's Amended Water Shortage Contingency Plan, as revised 3/7/22, Stage II outlines 2 additional
demand reduction actions. Palo Alto staff plans to recommend to Palo Alto City Council to implement the 2 additional demand reduction
actions in Stage II as well as adding a 2 day per week limit on ornamental landscape and lawn irrigation, except as needed for the health
of trees and other perennial non-turf plantings. The Palo Alto City Council may approve staff's proposals or take a different action or no
action.
Add additional rows as needed
How much is action going to
reduce the shortage gap?
When is shortage response
action anticipated to be
implemented?Is action
already being
implemented?
(Y/N)
ACTIONS: Demand Reduction, Supply
Augmentation, and Other Actions.
(Drop-down List)
These are the only categories that will
be accepted by the WUEdata online
submittal tool. Select those that apply.
Anticipated
Shortage
Level
Drop-down List of
State Standard
Levels (1 - 6) and
Level 0 (No
Shortage)
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TIMELINE
Upon review, discussion, and action by the UAC, staff will bring the Annual Water Shortage Assessment
Report to the City Council to consider its adoption. California Water Code Section 10632.1 requires the
Annual Water Shortage Assessment Report to be submitted to DWR by July 1 each year.
STAKEHOLDER ENGAGEMENT
Staff encourages interested parties to comment or provide feedback on the draft Annual Water
Shortage Assessment Report at the UAC or Council meeting where the report will be discussed, or to
submit written comments.
ENVIRONMENTAL IMPACT
Adoption of the 2022 Annual Water Shortage Assessment Report is exempt from California
Environmental Quality Act’s (CEQA) review pursuant to Water Code Section 10652.
Attachments:
• Attachment A: Presentation
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June 8, 2022 www.cityofpaloalto.org
2022 Annual Water Shortage Assessment Report
Utilities Advisory Commission
•
CITY OF
PALO ALTO
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2 www.cityofpaloalto.org
Beginning in 2022, every urban water supplier must:
1) Conduct an Annual Water Supply and Demand Assessment; and
2) Submit an Annual Water Shortage Assessment Report to the Department of
Water Resources
Required by the California Water Code Sections 10632(a) and 10632.1
Recommended Water Shortage Assessment Report consists of 5 tables showing that
Palo Alto’s existing and planned water conservation actions adequately address
anticipated potable water supply shortages
Annual Water Shortage Assessment Report •
CITY OF
PALO ALTO
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3 www.cityofpaloalto.org
Water Conservation Actions
Water Supply and Demand Assessment identified potable water shortage of 721 Acre Feet or 7% in FY
2023
Continued and planned implementation of water conservation actions projected to adequately
address shortage:
Permanent Water Use Restrictions (Palo Alto Municipal Code Section 12.32.010)
Stage I Water Use Restrictions (Resolution 10022, March 7, 2022)
Staff draft proposed Stage II Water Use Restrictions per State Board Emergency Regulations and
Governor ’s EO N-10-21
2-day per week watering restriction for ornamental landscape and lawn, except as required to
ensure the health of trees and other perennial non-turf plantings, consistent with county-wide
calls
•
CITY OF
PALO ALTO
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4 www.cityofpaloalto.org
Potable Water Shortage Assessment
= Auto calculated
= For manual input
Table 4(P): Potable Water Shortage Assessment1 Start Year:2022 Volumetric Unit Used2:AF
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun 3 Total
Anticipated Unconstrained Demand 1,213 1,105 1,063 1,031 810 689 648 534 650 855 1,097 1,080 10,776
Antici pated Total Water Supply 1,132 1,031 992 962 756 643 605 498 606 798 1,023 1,007 10,054
Surplus/Shortage w/o WSCP Action -81 -74 -71 -69 -54 -46 -43 -36 -43 -57 -73 -72 -721
% Surplus/Shortage w/o WSCP Action -7% -7% -7% -7% -7% -7% -7% -7% -7% -7% -7% -7% -7%
State Standard Shortage Level 1 1 1 1 1 1 1 1 1 1 1 1 1
Benefit from WSCP: Supply Augmentation 0.0
Benefit from WSCP: Demand Reduction 81 74 71 69 54 46 43 36 44 57 73 72 722
Revised Surplus/Shortage with WSCP 0 0 0 0 0 0 0 0 0 0 0 0 1
% Revised Surplus/Shortage with WSCP 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0% 0%
= From prior tables
Planned WSCP Actions
1Assessments are based on best available data at time of submitting the report and actual volumes could be different due to many factors.
2Units of measure (AF, CCF, MG) must remain consistent.
3When optional monthly volumes aren't provided, verify Tables 2 and 3 use the same columns for data entry and are reflected properly in Table 4 and make sure to use those same
columns to enter the benefits from Planned WSCP Actions. Please see directions on the shortage balancing exercise in the Table Instructions. If a shortage is projected, the supplier is
highly recommended to perform a monthly analysis to more accurately identify the time of shortage.
•
CITY OF
PALO ALTO
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5 www.cityofpaloalto.org
Planned Water Shortage Response Actions
Table 5 Continued
July 1,2022 to June 30,2023
Enter Amount
(Drop-down
List)
Select % or
Volume Unit
Start Month End Month
1 Expand Public Information Campaign Yes 135 AF July June
1 Offer Water Use Surveys Yes 32 AF July June
1 Provide Rebates on Plumbing Fixtures
and Devices Yes 32 AF July June
1 Provide Rebates for Landscape
Irrigation Efficiency Yes 32 AF July June
1 Provide Rebates for Turf Replacement Yes 32 AF July June
1 Landscape - Restrict or prohibit runoff
from landscape irrigation Yes 17 AF July June
1 Landscape - Limit landscape irrigation
to specific times Yes 17 AF July June
1 Landscape - Prohibit certain types of
landscape irrigation Yes 32 AF July June
1 Landscape - Other landscape restriction
or prohibition Yes 32 AF July June
1 CII - Other CII restriction or prohibition Yes 65 AF July June
1
Water Features - Restrict water use for
decorative water features, such as
fountains
Yes 17 AF July June
Table 5: Planned Water Shortage Response Actions
Add additional rows as needed
How much is action going to
reduce the shortage gap?
When is shortage response
action anticipated to be
implemented?Is action
already being
implemented?
(Y/N)
ACTIONS: Demand Reduction, Supply
Augmentation, and Other Actions.
(Drop-down List)
These are the only categories that will
be accepted by the WUEdata online
submittal tool. Select those that apply.
Anticipated
Shortage
Level
Drop-down List of
State Standard
Levels (1 - 6) and
Level 0 (No
Shortage)
1
Other - Customers must repair leaks,
breaks, and malfunctions in a timely
manner
Yes 17 AF July June
1 Other - Require automatic shut of hoses Yes 17 AF July June
1 Other - Prohibit use of potable water for
construction and dust control Yes 17 AF July June
1 Other - Prohibit use of potable water for
washing hard surfaces Yes 32 AF July June
2 CII - Lodging establishment must offer
opt out of linen service No 45 AF July June
2 CII - Restaurants may only serve water
upon request No 45 AF July June
2 Landscape - Limit landscape irrigation
to specific days No 135 AF July June
NOTES: Table 5 shows the actions that Palo Alto plans to take based on the supply and demand assessment and that Palo Alto staff plan
to recommend to the Palo Alto City Council as a result of Executive Order N-7-22 emergency regulations; Palo Alto has 8 permanent
water use restrictions in the Palo Alto Municipal Code Section 12.32.010
https://codelibrary.amlegal.com/codes/paloalto/latest/paloalto_ca/0-0-0-69362#JD_Chapter12.32; Palo Alto's Amended Water Shortage
Contingency Plan, as revised 3/7/22, Stage I, outlines 7 additional demand reduction actions. Palo Alto City Council implemented the
Stage I actions on 3/7/22. Palo Alto's Amended Water Shortage Contingency Plan, as revised 3/7/22, Stage II outlines 2 additional
demand reduction actions. Palo Alto staff plans to recommend to Palo Alto City Council to implement the 2 additional demand reduction
actions in Stage II as well as adding a 2 day per week limit on ornamental landscape and lawn irrigation, except as needed for the health
of trees and other perennial non-turf plantings. The Palo Alto City Council may approve staff's proposals or take a different action or no
action.
•
CITY OF
PALO ALTO
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The Utilities Advisory Commission recommends Council
adopt the 2022 Annual Water Shortage Assessment
Report.
RECOMMENDED MOTION •
CITY OF
PALO ALTO
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City of Palo Alto (ID # 14175)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type:
City of Palo Alto Page 1
Title: Discussion and Update to the 2022 Wildfire Safety Mitigation Plan
From: Director of Utilities
Lead Department: Utilities
Recommendation
Staff recommends that the UAC receive the Wildfire Mitigation Plan Update.
Executive Summary
Each year, electric utilities are required to update their Wildfire Mitigation plans, present those
plans in a noticed public meeting, then submit the plan by July 1 to the State’s Wildfire Safety
Advisory Board.1 Staff updated the plan earlier this year, will present the plan at today’s
meeting, and intends to submit the plan in late June, pending any UAC discussion.
Background
Utilities Department Staff prepared our first Wildfire Mitigation Plan in 2019, after the passage
of a new law requiring such plans of all electric utilities. The law requires specific plan elements,
including a description of the preventive strategies used to minimize the risk of electric lines
and equipment causing catastrophic wildfires, protocols for disabling reclosers and
deenergizing when necessary, and twelve other elements. The first plan was presented to and
accepted by the City Council on January 21, 2020 (Staff Report ID 10670). The law requires an
annual update to the original plan, with a comprehensive revis ion at least once every three
years.2 As such, staff presented the updated plan in 2021 to the UAC (Staff Report ID 12190)
and the 2022 update is Linked Here. The redlines appearing in the update are at the request of
the Wildfire Safety Advisory Board and the plan will be submitted as such to easily show
changes.
Discussion
After submitting the 2021 updates, the Wildfire Safety Advisory Board reviewed the plans from
each utility and offered comments and suggestions for future iterations. Some comments and
suggests were intended broadly for all entities reporting and some for each specific agency;
1 See Public Utility Code 8387.
2 “Update” and “comprehensive revision” are undefined in statute. Palo Alto staff and other POUs take “update” to
mean simply bringing the original plan up to date, with few meaningful changes and “comprehensive revision” to
mean an in-depth review of each plan element, with significant changes made as needed to the original plan.
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many of the comments directed to Palo Alto specifically were favorable.3 Below is a summary of
the key changes between the 2021 and 2022 updates:
• At the request of the Wildfire Safety Advisory Board, we moved the website placement
of the original plan and 2021 update to make it easier to find and we included the
Board’s Context Table (page 3)
• Dates of past years’ public presentations on the plan were added (page 24)
• Added more context to community outreach efforts during a fire (page 25)
• Added the Response and Communications Procedure for Public Safety Power Shutoff
(Appendix G)
• Updates made to the status of reported projects, including: the installation of a weather
station, progress on undergrounding lines, assessments for emergency back-up
generators, and more (pages 18 – 20 and Appendix E)
• General wordsmithing for clarity
Timeline and Resource Impact
This update does not have any immediate resource impact besides staff time. Ongoing and
proposed activities noted in the plan are and will be approved through the Capital and
Operating Budget process. The plan update will be submitted to the Wildfire Safety Advisory
Board by July 1, 2022, as is legally required.
Stakeholder Engagement
The annual presentation of plan iterations in a publicly noticed meeting affords an
opportunity for stakeholders to provide comments to the UAC and staff. Additionally, all
versions of the plan are posted on the Utilities Department website for public review.
Environmental Review
The UAC’s receipt of this report and presentation is not a project requiring California
Environmental Quality Act review, because it is an administrative governmental activity which
will not cause a direct or indirect change in the physical environment.
3 See “Guidance Advisory Opinion for the 2022 Wildfire Mitigation Plans of Electric Publicly Owned Utilities and
Rural Electric Cooperatives,” page 15 for one example: “Palo Alto’s proactive attention to consideration of
pumping water uphill in preparation for a potential wildfire and/or PSPS event is commendable.”
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City of Palo Alto (ID # 14279)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type:
City of Palo Alto Page 1
Title: Staff Request for UAC Feedback on the Development of the Electric
Utility’s Integrated Resource Plan
From: Director of Utilities
Lead Department: Utilities
REQUEST
Staff seeks UAC feedback on a proposed scope and work plan for the next update of the City’s
Integrated Resource Plan (the 2023 IRP) for the electric utility, which will be developed in compliance
with Senate Bill 350 (Clean Energy and Pollution Reduction Act). There is no recommended action.
EXECUTIVE SUMMARY
Integrated resource planning is an analysis-driven approach that utilities have long used to ensure that
they provide sufficient resources to reliably meet forecasted customer electrical energy and capacity
needs in the most cost-effective way, while considering a comprehensive set of supply and demand
resources (on equal footing) and satisfying environmental and other public policy objectives. In addition,
it provides the utility an opportunity to seek community input and incorporate that feedback into its
roadmap for the future.
The City is now beginning the process of updating its 2018 IRP, as required by state legislation (Senate
Bill 350). While this update will ensure that the City manages its electric resources consistent with state
and federal regulatory and legislative requirements, the City’s climate sustainability goals, and the
Utilities Department’s strategic planning objectives, it will also provide a basis for the following key
decisions and policies (among others) related to the electric portfolio in the 2024 to 2035 period, which
is the planning horizon for the new IRP:
1. Western Contract – Evaluate whether to renew the City’s hydroelectric contract with the
Western Area Power Administration (WAPA), which expires at the end of 2024, or replace this
contract with other carbon-free resources; and
2. California-Oregon Transmission Project (COTP) – Evaluate the best use for the City’s 51 MW
share of COTP after the City’s layoff of that asset expires at the end of 2023.
In addition to these key strategic decisions, the IRP will address Palo Alto’s long-term load forecast, giving
particular consideration to the City’s electrification efforts and aggressive climate and sustainability
goals. However, the IRP is not intended to be a forum for reconsidering the Utilities Strategic Plan; for
designing or developing new customer programs; for developing new initiatives to meet the City’s
Sustainability and Climate Action Plan (S/CAP) objectives; or for doing any significant distribution system
planning.
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Staff seeks UAC and community feedback on this analysis framework and process for developing the IRP
over the next 18 months. The UAC and the community will be provided subsequent updates and
opportunities to offer additional feedback as staff carries out the analysis.
BACKGROUND
An integrated resource plan (IRP) is a tool traditionally used by utilities to provide a roadmap for meeting
forecasted electricity demand through a combination of supply-side resources (i.e. local and remote
generation resources) and demand-side resources (e.g. customers installing energy storage systems or
energy-efficient equipment and appliances) over a specified future period. A comprehensive decision
analysis modeling tool is used to evaluate costs, benefits, and uncertainties related to various supply and
demand portfolio alternatives with the objective of identifying the least-cost, least-risk portfolio of
resources. Like all IRPs, this effort will take the following factors into account in identifying solutions:
1. Loading Order. Pursue all cost-effective energy efficiency and demand-side resources before
contracting for new supply-side resources.
2. Regulatory Compliance. Comply with state and federal regulatory requirements (e.g. Renewable
Portfolio Standards) and other standards as appropriate (e.g. CAISO capacity requirements).
3. Council-adopted Climate Goals and Carbon Neutral Plan objectives. Reduce carbon intensity of
the electric portfolio by utilizing 1) maximum procurement of long-term Renewable Portfolio
Standard (RPS)-eligible renewables; 2) existing large hydroelectric resources; and 3) Renewable
Energy Credits (REC) when long-term resources are not sufficient.
4. Customer Preferences. Facilitate customer preference for other resources (e.g. local solar or
storage) and facilitate the deployment in a cost-effective manner.
5. Cost. Identify the most cost-effective approach that addresses Council-adopted objectives.
Manage existing resources to maximize value.
6. Risk Management. Structure the portfolio or add mitigations to manage known risks (e.g.
market price risk or hydroelectric variability) and build flexibility into the portfolio to address
other less quantifiable risks (e.g. regulatory uncertainty) through diversification of suppliers,
contract terms, and resources, and through the use of creditworthy counterparties when
appropriate.
The need to conduct a traditional IRP has been minimized significantly through California’s and the City’s
adoption of several legislative initiatives and policies which mandate how resources will be procured—
e.g. through loading order mandates, targets for roof-top solar installations, renewable portfolio
standards, and capacity planning reserves. However, in October 2015, Governor Jerry Brown signed
Senate Bill 350 (SB 350) into law, which among other things requires publicly owned utilities (POU)
serving loads greater than 700,000 megawatt hours per year to develop, adopt, and submit an IRP to the
California Energy Commission (CEC), and update it every 5 years. One of the main objectives of SB 350 is
to ensure that POUs are on track to help the State meet its greenhouse gas emission reduction target of
40% below 1990 levels by 2030.
The City adopted its first IRP under the SB 350 requirements on December 3, 2018 (Staff Report 9761).1
In addition to the IRP itself, the Council also approved:
1 Prior to the 2018 IRP, the City used a similar tool, referred to as the Long-term Electric Acquisition Plan (LEAP), as
a framework for its supply and demand resource policies and investment decisions. The LEAP was different than a
traditional IRP, in that its primary focus was on how to manage the electric portfolio consistent with RPS and other
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1) A set of four standardized tables that the CEC’s IRP regulations required POUs to submit with
their IRPs;
2) IRP Objective and Strategies (Attachment A) to guide future analysis and decisions; and
3) An IRP Work Plan (Attachment B) with a set of new initiatives and timelines for their completion,
which staff recommended undertaking in order to prepare the City’s electric supply portfolio for
the upcoming shifts in the electric utility industry.
Table 1 below lists the seven new initiatives proposed in the City’s 2018 IRP Work Plan, along with the
current status of each one.
Table 1: Summary of 2018 IRP Work Plan Initiatives
Work Plan Initiative Current Status
1. Evaluate the merits of committing to a new 30-year contract
with WAPA starting in 2025.
Ongoing—will be part of
2024 IRP.
2. Evaluate the merits of rebalancing the electric supply portfolio
to lower its seasonal and daily market price exposure, by more
closely balancing the City’s long-term supplies with its hourly
and monthly electric loads.
Ongoing—will be part of
2024 IRP.
3. Evaluate how to best utilize the City’s share of the California
Oregon Transmission Project (COTP), when the long-term layoff
of this asset ends in 2024.
Ongoing—will be part of
2024 IRP.
4. In addition to ensuring 100% of City’s annual electricity energy
needs are met with carbon neutral supplies (on a kWh basis),
evaluate the carbon content of the electric portfolio on an
hourly basis, and recommend the merits of buying carbon
offsets to ensure the carbon content of the cumulative hourly
portfolio is zero on an annual basis.
Completed—Carbon
Neutral Plan updated to
use an hourly carbon
accounting methodology in
August 2020 (Staff Report
11556).
5. Investigate the merits and economics of monetizing excess
renewable energy certificates to minimize the cost of
maintaining an RPS compliant and carbon neutral electricity
supply portfolio.
Completed—REC Exchange
Program approved in
August 2020 (Staff Report
11556).
6. Explore greater synergistic opportunities with NCPA and other
agencies – such as newly formed community choice
aggregators – to lower Palo Alto’s operating costs and
rebalance the supply portfolio.
Ongoing—staff has
engaged with new CCAs in
numerous transactions and
knowledge-exchange
efforts.
7. Undertake a competitive assessment for the electric utility
within the context of the large proliferation of customer-sited
DER technologies, electrification initiatives, changing customer
expectations, and potential regulatory changes. Develop
contingencies to address the potential for large changes in the
City’s load level or load profile.
Ongoing.
mandates rather than an exclusive focus on portfolio optimization. The City adopted its first LEAP in November
2001 (CMR: 425:01), with subsequent updates in 2002 (CMR: 398:02), 2007 (CMR: 158:07), and 2011 (Staff Report
1317).
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DISCUSSION
SB 350 required POUs to adopt their initial IRPs by January 1, 2019, with subsequent updates required
every five years thereafter. An update of the City’s last IRP is therefore needed by January 2024; an
updated IRP will also provide a basis for several key decisions and policies related to the electric portfolio
in the 2024 to 2035 planning horizon.
Objectives of the 2024 IRP
At a minimum, Section 9621 of the California Public Utilities Code requires that the City’s IRP:
1. Meet GHG emissions targets that reflect the electricity sector’s contribution to achieving the
economy-wide greenhouse gas emissions reductions of 40 percent from 1990 levels by 2030;
2. Ensure procurement of at least 60 percent eligible renewable energy resources by 2030;
3. Meet the following goals:
a. Minimize impacts on ratepayers’ bills;
b. Ensure system and local reliability;
c. Enter into long- and short-term contracts for electricity and RECs;
d. Strengthen the diversity, sustainability, and resilience of the bulk transmission and
distribution systems, and local communities;
e. Enhance distribution systems and demand-side energy management;
4. Include details of the utility’s rate design that support transportation electrification, and existing
or planned incentives to support transportation electrification, including rebates. The rate design
shall include details for all applicable transportation sectors, including, but not limited to, on-
road and off-road vehicles in the light-, medium-, and heavy-duty sectors. Each IRP shall also
include information about the utility’s customer education and outreach efforts to inform utility
customers of available incentives and decision-making tools, such as cost calculators or cost
estimates that can assist customers in predicting the cost of paying for electricity for these
vehicles; and
5. Consider the role of existing renewable generation, grid operational efficiencies, energy storage,
and distributed energy resources, including energy efficiency, in helping to meet energy and
reliability needs the hours of net peak demand, while reducing the need for new generation and
transmission resources in achieving the state’s energy goals at the least cost to ratepayers;2
6. Address the following procurement topics:
a. Energy efficiency and demand response resources;
b. Energy storage;
c. Transportation electrification;
d. A diversified procurement portfolio consisting of both short-term and long-term
electricity, electricity-related, and demand response products;
e. Resource adequacy requirements.
In addition to satisfying these obligations, staff intends to use this IRP process to help the City make two
major decisions regarding its supply portfolio (which were also listed in the City’s 2018 IRP Work Plan):
(a) whether to renew the City’s contract with the WAPA for hydroelectric resources from the Central
Valley Project (CVP), which expires at the end of 2024; and (b) what to do with the City’s share of the
California-Oregon Transmission Project (COTP) after the City’s layoff of that asset expires at the end of
2023.
2 Note that items 4 and 5 are new requirements adopted by the state after the 2018 IRP submission date.
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As staff undertakes this IRP effort, it will do so while maintaining consistency with the City of Palo Alto
Utilities (CPAU) 2018 Mission Statement: “To provide safe, reliable, environmentally sustainable and
cost-effective services.” In addition, staff will be mindful of CPAU’s supply portfolio management
principles:
1. Demand and Supply Resource Acquisition – Meet customer electricity needs through the
acquisition of least total cost energy and demand resources including an assessment of the
environmental costs and benefits.
2. Supply Cost Management – Manage supply portfolio cost uncertainty to meet rate and reserve
objectives.
3. Local Distributed Generation and Transmission – Enhance supply reliability to meet City and
customer needs by pursuing opportunities including transmission system upgrades and local
generation.
Finally, staff will use this IRP development process as an opportunity to engage the community and
solicit their input into these major strategic decisions that will be made along the way. Public
participation and feedback are valuable components of the IRP process. Outside of speaking at UAC and
Council meetings, customers rarely have an opportunity to weigh in directly on long-term portfolio
management decisions; however, during this process staff will make an effort to more broadly survey
customers about the direction they would like CPAU’s electric supply portfolio to go. For example, in
evaluating the WAPA and COTP decisions, staff’s primary focus will be on minimizing total portfolio cost
and risk (while adhering to existing Council-adopted policies and state mandates). However, staff seeks
feedback from the UAC and the community as to whether to give any weight to other factors in the
evaluation process—such as the geographic location of resources; technology diversification of the
supply portfolio; or matching the portfolio’s total output to the City’s load profile in order to minimize
load-balancing market transactions.
Proposed 2024 IRP Scope
While an IRP is typically a lengthy report that provides a long-term roadmap for utility planners, it is
important to remember what its scope encompasses: Selecting a set of supply-side and demand-side
resources to meet forecasted customer demand, while minimizing cost, risk, and environmental impact.
While this scope is broad, it is also notable for what it excludes. This scope does not include updating the
Utilities Strategic Plan (which was approved in 2018); it does not include designing or developing new
customer programs; it does not involve developing new initiatives to meet the Sustainability and Climate
Action Plan (S/CAP) objectives; and it includes only a very limited focus on distribution system
planning (i.e., only to the extent that when evaluating resource portfolio mixes that involve a large
amount of distributed energy resources (DERs), the IRP analysis must account for the cost of investing in
the distribution system to enable these DERs to be adopted). Maintaining these limitations on the IRP’s
scope is critical to ensuring the community can focus on the important long-term supply portfolio
decisions that need to be made soon, and therefore critical to the success of the IRP process.
NEXT STEPS
The schedule and structure of the IRP process is guided in large part by requirements imposed by SB 350
and CEC guidelines to implement it.3 However, as noted earlier, the timing of the IRP process is also
dictated by the need to make long-term resource investment decisions around the City’s supply portfolio
3 SB 350 requires the development and submission of an updated IRP to the CEC no later than January 1, 2024.
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(related to the WAPA hydroelectric contract and the end of the COTP layoff). To help inform the analysis
around those decisions, staff has developed a detailed workplan (Attachment C) that includes:
• Acquiring electric portfolio modeling and optimization software;
• Issuing a renewable energy and storage request for proposals (RFP) to develop a set of
alternatives to compare the extended WAPA hydroelectric contract against;
• Conducting and sharing portfolio rebalancing and optimization analysis; and
• Researching options for the use of COTP after the current layoff ends, and meeting with other
COTP owners to explore these options.
In addition to this internal work, to address the City’s electric portfolio planning needs in a
comprehensive IRP update and meet SB 350’s requirements, staff proposes a series of public discussions
on a range of topics over the next 12 to 18 months. These discussions will enable the public to have a
better understanding of the issues and decisions facing the Electric Utility and to provide input and
direction early in the process. Table 2 below provides an overview of these proposed meetings and their
objectives.
Table 2: Proposed 2024 IRP Public Meetings
Meeting Topic Meeting Objectives/Goals Date / Forum
1. IRP Overview and
Work Plan
Provide a high-level overview of IRP requirements,
guiding principles, scope, and timeline.
June 2022
UAC
2. COTP and WAPA Base
Resource Discussion
Provide an overview of COTP and the WAPA
hydroelectric contract, and a high-level discussion of
the costs, benefits, and uncertainties around each.
November 2022
UAC
3. Load Forecast Scenario
Planning
Discuss the role of electrification, electric vehicles,
energy efficiency, local/distributed generation, and
storage on the City’s load forecast and distribution
system planning needs.
December 2022
UAC
4. Portfolio Optimization
Results and Feedback
Overview of electric load forecast, existing supply
resources, renewable RFP results, and initial results
of portfolio optimization analysis.
February 2023
UAC
5. Preliminary Long-term
Plan
Present refined portfolio optimization analysis
results and staff’s recommended supply portfolio.
June 2023
UAC
6. Proposed Final IRP Present draft IRP report and implementation plan. August 2023
UAC
7. Final IRP Seek approval of IRP report and implementation
plan.
November 2023
Council
Staff will incorporate the UAC’s input on the proposed IRP work plan and portfolio analysis process, and
will return to discuss the initial findings of the analysis in the future.
RESOURCE IMPACT
There is no direct resource impact as a result of the proposed IRP work plan. Work will be performed
almost entirely by existing staff, who will collaborate with staff from NCPA and other municipal utilities in
this effort when possible. The cost of acquiring portfolio optimization software and a minimal amount of
support from consultants (estimated at about $100k) has already been accounted for in the annual
Utilities Department budget.
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POLICY IMPLICATIONS
There is no direct policy impact associated with the proposed work plan, but any changes made through
IRP will affect policy related to electric portfolio management. Staff will also update the IRP to ensure
consistency with the City’s sustainability goals as established in its Sustainability and Climate Action
Plan.
ENVIRONMENTAL REVIEW
The Utilities Advisory Commission’s discussion of the IRP work plan does not meet the definition of a
project under Public Resources Code 21065 and is therefore California Environmental Quality Act (CEQA)
review is not required.
Attachments:
• Attachment A: 2018 IRP Objective & Strategies
• Attachment B: 2018 IRP Work Plan Initiatives
• Attachment C: Proposed 2024 IRP Work Plan
• Attachment D: Presentation
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Attachment A
2018 Electric Integrated Resource Plan (EIRP)
Objective and Strategies
EIRP Objective
To provide safe, reliable, environmentally sustainable and cost-effective electric resources and
services to all customers.
EIRP Strategies
1. Pursue an Optimal Mix of Supply-side and Demand-side Resources: When procuring to
meet demand, pursue an optimal mix of resources that meets the EIRP Objective, with
cost-effective energy efficiency, distributed generation, and demand-side resources as
preferred resources. Consider portfolio fit and resource uncertainties when evaluating
cost-effectiveness.
2. Maintain a Carbon Neutral Supply: Maintain a carbon neutral electric supply portfolio
to meet the community’s greenhouse gas (GHG) emission reduction goals.
3. Actively Manage Portfolio Supply Cost Uncertainties: Structure the portfolio or add
mitigations to manage short-term risks (e.g. market price risk and hydroelectric
variability) and build flexibility into the portfolio to address long-term risks (e.g. resource
availability, customer load profile changes, and regulatory uncertainty) through
diversification of suppliers, contract terms, and resource types.
4. Manage Electric Portfolio to Ensure Lowest Possible Ratepayer Bills: Pursue resources
in a least-cost, best-fit approach in an effort to ensure ratepayer bills remain as low as
possible, while adhering to Council-adopted sustainability, rate, and financial objectives
and guidelines.
5. Partner with External Agencies to Implement Optimization Opportunities: Engage and
partner with external agencies to maximize resource value and optimize operations.
6. Maintain Flexible Supplies to Effectively Meet Changes in Customer Loads & Load
Profiles: Maintain electric supply resource flexibility in anticipation of potential changes
in customer loads due to distributed energy resources, efficiency, electrification, or for
other reasons.
7. Ensure Reliable and Low-Cost Transmission Services: Work with the transmission
system operator to receive reliable service in a least cost manner.
8. Support Local Electric Supply Resiliency: Coordinate supply portfolio planning with
utility-wide efforts to support local measures and programs that enhance community
electric supply resiliency.
9. Comply with State and Federal Laws and Regulations: Ensure compliance with all
statutory and regulatory requirements for energy, capacity, reserves, GHG emissions,
distributed energy resources, efficiency goals, resource planning, and related initiatives.
4.a
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Attachment B
2018 EIRP Strategies & Related New Initiatives
There are a number of new initiatives and numerous on-going tasks related to implementing
the EIRP Strategies. These activities are supported by about six to eight CPAU staff, both from
the supply side and demand-side (or customer) programs. In addition, CPAU relies on joint
action agencies and external service providers to implement programs and initiatives. Supply
and customer program staff also coordinates with retail rate development, distribution system
engineering, and operations staff to implement programs and investments in an integrated
manner.
Described below are the nine strategies and eight new initiatives that are expected to be
undertaken in the next three to six years. Work tasks related to on-going activities have not
been called out separately.
EIRP Strategies & Related New Initiatives
1. Pursue an Optimal Mix of Supply-side and Demand-side Resources: When procuring to
meet demand, pursue an optimal mix of resources that meets the EIRP Objective, with
cost-effective energy efficiency, distributed generation, and demand-side resources as
preferred resources. Consider portfolio fit and resource uncertainties when evaluating
cost-effectiveness.
a. Initiative #1: Evaluate the merits of committing to a new 30-year contract with
Western starting in 2025. [Recommendation on initial commitment to the UAC in
early 2020; recommendation on final commitment in early 2024.]
b. Initiative #2: Evaluate the merits of rebalancing the electric supply portfolio to
lower its seasonal and daily market price exposure, by more closely balancing the
City ’s long-term supplies with its hourly and monthly electric loads. [Initial
scoping assessment report to the UAC by December 2019.]
c. Initiative #3: Evaluate how to best utilize the City’s share of the California-
Oregon Transmission Project (COTP), when the long-term layoff of this asset
ends in 2024. [Initial assessment report to UAC by December 2019, in tandem
with Initiative #2 initial scoping assessment report.]
d. Continue ongoing evaluation of all cost-effective distributed energy resources
(DERs), such as energy efficiency, distributed generation, energy storage, and
demand response. Update forecasts of DER impacts on retail sales and load
shapes for use in strategic planning, rate-making, and budget forecasting. [Initial
assessment to be completed in Distributed Energy Resource (DER) and Customer
Program Plan for Council approval by June 2019.]
2. Maintain a Carbon Neutral Supply: Maintain a carbon neutral electric supply portfolio
to meet the community’s greenhouse gas (GHG) emission reduction goals.
a. Initiative #4: In addition to ensuring 100% of City’s annual electricity energy
needs are met with carbon neutral supplies (on a kWh basis), evaluate the
carbon content of the electric portfolio on an hourly basis, and recommend the
merits of buying carbon offsets to ensure the carbon content of the cumulative
4.b
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Attachment B
hourly portfolio is zero on an annual basis. Also evaluate the manner in which the
City communicates with customers about the carbon content of the electric
portfolio. [Initial staff recommendation to the UAC by December 2019.]
3. Actively Manage Portfolio Supply Cost Uncertainties: Structure the portfolio or add
mitigations to manage short-term risks (e.g. market price risk and hydroelectric
variability) and build flexibility into the portfolio to address long-term risks (e.g. resource
availability, customer load profile changes, and regulatory uncertainty) through
diversification of suppliers, contract terms, and resource types.
a. This is an on-going active management strategy; no new initiatives are planned.
4. Manage Electric Portfolio to Ensure Lowest Possible Ratepayer Bills: Pursue resources
in a least-cost, best-fit approach in an effort to ensure ratepayer bills remain as low as
possible, while achieving other Council-adopted sustainability, rate, and financial
objectives.
a. Initiative #5: Investigate the merits and economics of monetizing excess
renewable energy certificates to minimize the cost of maintaining an RPS
compliant and carbon neutral electricity supply portfolio. [Initial staff
recommendation to the UAC by December 2019.]
5. Partner with External Agencies to Implement Optimization Opportunities: Actively
engage and partner with external agencies to maximize resource value and optimize
operations.
a. Initiative #6: Explore greater synergistic opportunities with NCPA and other
agencies – such as newly formed community choice aggregators – to lower Palo
Alto’s operating costs and rebalance the supply portfolio. [Initial assessment to
UAC by December 2019.]
6. Manage Supplies to Meet Changing Customer Loads and Load Profiles: Maintain
electric supply resource flexibility in anticipation of potential changes in customer loads
due to distributed energy resources, efficiency, electrification, or for other reasons. At
the same time, use retail rates and other available tools to influence customer load
changes in a manner that minimizes overall costs and achieves other Council objectives.
a. Initiative #7: Implement 2018 Utilities Strategic Plan Priority 4, Strategy 4,
Action 2 by undertaking a competitive assessment for the electric utility within
the context of the large proliferation of customer-sited DER technologies,
electrification initiatives, changing customer expectations, and potential
regulatory changes. Develop contingencies to address the potential for large
changes in the City’s load level or load profile. [Initial assessment to UAC in
December 2020.]
7. Ensure Reliable and Low-cost Transmission Services: Work with the transmission
system operator to receive reliable service in a least-cost manner.
a. This is an on-going activity; no new initiatives are planned.
4.b
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Attachment B
8. Support Local Electric Supply Resiliency: Coordinate supply portfolio planning with
utility-wide efforts to support local measures and programs that enhance community
electric supply resiliency.
a. On-going supporting role in utility-wide efforts.
9. Comply with State and Federal Laws and Regulations: Ensure compliance with all
statutory and regulatory requirements for energy, capacity, reserves, GHG emissions,
distributed energy resources, efficiency goals, resource planning, and related initiatives.
a. Ongoing activities in collaboration with NCPA, CMUA and other joint action
agencies.
4.b
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Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Integrated Resource Plan
Review IRP requirements
Review other utilities' IRPs
RFP for portfolio optimization software
Research COTP post-layoff options
Issue Renewable/Storage RFP
UAC - Kickoff/Scoping meeting X
COTP post-layoff options analysis
Evaluate Renewable RFP responses
Perform portfolio optimization analysis
UAC - COTP & Western discussion X
UAC - Load forecasting discussion X
UAC - Portfolio optimization results X
UAC - Preliminary long-term plan X
UAC - Final IRP report X
Finance - Final IRP report X
Council - Final IRP report X
2022 2023PROJECT / ACTIVITY
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June 8, 2022 www.cityofpaloalto.org
Electric Integrated Resource Plan Kickoff Discussion
Staff: James Stack
4.d
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PURPOSE OF PRESENTATION
•Provide a refresher course on Integrated Resource Planning
•Palo Alto’s resource planning history
•California IRP requirements
•Introduce key policy questions:
•Western Base Resource contract renewal vs. replacement
•California-Oregon Transmission Project (COTP) usage
•Propose an approach to develop a new IRP for the 2024-2035 planning
horizon
•Get UAC feedback on the proposed Work Plan including future
discussion items and timeline
2
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PART 1: INTEGRATED RESOURCE PLANNING OVERVIEW
June 8, 2022 www.cityofpaloalto.org
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WHAT IS AN INTEGRATED RESOURCE PLAN?
•A roadmap for meeting forecasted demand through a combination of
supply-side (i.e. generation) and demand-side (e.g. efficiency,
demand response, storage) resources
•Analysis framework for identifying the most cost-effective, least-risk
portfolio of resources
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FACTORS CONSIDERED IN AN IRP
•Loading Order –Pursue all cost-effective energy efficiency and demand-
side resources
•Regulatory Compliance –Comply with all regulatory requirements
•Climate Goals –Maintain a carbon neutral electric portfolio
•Customer Preferences –Facilitate individual customer preferences for
alternative resources
•Cost –Identify the most cost-effective approach to meet policy directives
•Risk Management –Structure the portfolio or add mitigations to manage
known risks
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HISTORY OF CPAU PLANNING INITIATIVES (1992-Present)
•1992: City’s first ten-year Electric Integrated Resource Plan (IRP)
•2001: City’s first Long-term Electric Acquisition Plan (LEAP)
•2002: California and Palo Alto adopts first Renewable Portfolio Standard
•2006: California adopts Global Warming Act –(1990 levels by 2020 –15%)
•2007: City’s Climate Protection Plan –sets GHG reduction goals
•2007: LEAP Updated –focus on loading order and RPS update
•2007: First 10-year Energy Efficiency Plan (last updated in 2017)
•2010-11: LEAP Updated –focus on carbon reduction goals
•2017-18: City completes first IRP under SB 350 requirements (through 2030)
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CALIFORNIA’S IRP REQUIREMENTS (SB 350)
•Help the state meet its GHG reduction targets (40% below 1990 levels by
2030)
•Ensure procurement of at least 60 percent eligible renewable energy
resources by 2030
•Minimize impacts on ratepayers’ bills
•Ensure system and local reliability
•Enter into long-and short-term contracts for electricity and RECs
•Strengthen the diversity, sustainability, and resilience of the bulk transmission
and distribution systems, and local communities
•Enhance distribution systems and demand-side energy management
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CALIFORNIA’S IRP REQUIREMENTS (SB 350), cont.
•Address the following procurement topics:
•Energy efficiency and demand response resources
•Energy storage
•Transportation electrification
•A diversified procurement portfolio
•Resource adequacy requirements
•Include details of the utility’s rate design that support transportation
electrification
•Consider the role of various demand and supply resources in meeting energy
and reliability needs in the hours of net peak demand, while reducing the
need for new resources
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PART 2: KEY POLICY QUESTIONS
June 8, 2022 www.cityofpaloalto.org
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WESTERN BASE RESOURCE CONTRACT DECISION
•Central Valley Project (CVP) is owned and operated by the U.S.
Bureau of Reclamation
•CVP’s electric output is marketed by the Western Area Power
Administration (WAPA) under the Western Base Resource contract
(2005-2024)
•Total CVP Capacity: 2,112 MW
•Palo Alto’s allocation: 12.3%
•~360 GWh in an average year
•~40% of City’s supply
•Annual WBR contract cost: ~$12 million
•Palo Alto has the option to renew the WBR contract for 2025-2054
•Deadline of June 30, 2024 to reduce/terminate the renewed WBR contract
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PALO ALTO’S ELECTRIC LOAD & SUPPLY PORTFOLIO
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CALIFORNIA-OREGON TRANSMISSION PROJECT DECISION
•COTP is a 340-mile long, 1,600 MW, 500 kV transmission power
project between Southern Oregon and Central California
•Owned by the Transmission Association of Northern California (a
joint powers agency of which Palo Alto is a member), along with the
City of Redding, WAPA, two California water districts, and PG&E
•Palo Alto’s share is 51 MW (4% of the TANC portion of COTP)
•Due to low utilization, Palo Alto laid off its share of COTP (for 2008-
2023) to SMUD, TID, and MID
•The layoff recipients are covering Palo Alto’s debt costs during the layoff
period, but Palo Alto will owe a large payment to them at the end of the
layoff for long-term improvements made to the project during the layoff
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PART 3: PROPOSED 2023 IRP OBJECTIVES & WORK PLAN
June 8, 2022 www.cityofpaloalto.org
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OBJECTIVES OF THE IRP DEVELOPMENT PROCESS
•SB 350 Compliance –Fully comply with all IRP requirements
•Western Decision –Evaluate whether to renew the WBR contract for
2025+, or reduce/terminate it and replace it with other resources
•COTP Decision –Evaluate what to do with COTP when the layoff ends
in 2024: use it ourselves, negotiate a new layoff, or let CAISO use it
•Community Engagement –Solicit public input into strategic decisions
about the supply portfolio
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OUTSIDE THE IRP SCOPE
•The IRP is not going to:
•Update the Utilities Strategic Plan
•Design new customer programs
•Design new S/CAP initiatives
•Provide any serious distribution system planning
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NEXT STEPS
•Issue a renewable energy / storage RFP, so we have alternative
options to compare the renewed WAPA contract against
•RFP will seek local generation offers, but these are expected to be limited
•Contract for supply portfolio modeling and optimization software
•Use software to perform portfolio optimization analysis, including
comparison of WAPA contract and other alternatives
•Work with a consultant to analyze post-layoff uses of COTP, and
discuss a potential new layoff with other COTP owners
•Solicit public input on the direction of the supply portfolio
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PROPOSED IRP WORK PLAN
Meeting Topic Date / Forum
IRP Overview and Work Plan June 2022 / UAC
COTP and Western Base Resource Discussion November 2022 / UAC
Load Forecast Scenario Planning December 2022 / UAC
Portfolio Optimization Results and Feedback February 2023 / UAC
Preliminary Long-term Plan June 2023 / UAC
Proposed Final IRP August 2023 / UAC
Final IRP November 2023 / Council
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Jim Stack, Ph.D.
Senior Resource Planner
james.stack@cityofpaloalto.org
(650) 329-2314
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City of Palo Alto (ID # 14288)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type: VII. NEW BUSINESS
City of Palo Alto Page 1
Title: Discussion of Advanced Metering Infrastructure Opt -Out and Electric
Meter Remote Disconnect and Reconnect Policies
From: Director of Utilities
Lead Department: Utilities
Request
Staff seeks UAC feedback on two new policies associated with advanced metering infrastructure (AMI):
1. AMI Opt-Out Policy (Attachment A)
2. Electric Meter Remote Disconnect/Reconnect Policy (Attachment B)
The draft policies presented here for discussion purposes highlight AMI-specific contents that would be
added to existing Utilities Rules and Regulations. Final policies will be incorporated into the Utilities
Rules and Regulations 9 (“Discontinuance, Termination and Restoration of Service”) (Attachment C) and
10 (“Meter Reading”) (Attachment D) as Rule updates for Council approval before they take effect.
Executive Summary
AMI is a foundational technology that is becoming a standard in the utilities industry and will improve
customer experience while enabling CPAU to operate more effectively. An AMI-based smart grid
system will empower customers to more efficiently utilize utility supplies, facilitate customer adoption
of distributed energy resources (DER) such as solar photovoltaics, energy storage, and electric vehicles,
and enable the timely detection of water leaks. AMI will also enable CPAU to optimize operations and
improve reliability by reducing restoration time for outages. AMI will be a critical system to meet the
community’s greenhouse gas reductions goals by enabling time-of-use (TOU) electricity rates and to
encourage the use of electrical appliances and charging EVs during periods of the day when electricity
cost is low.
Based on previous feedback from the UAC, CPAU will provide customers an alternative to a standard
advanced meter installation through the AMI Opt-Out Policy. Electric and gas residential customers will
be given the opportunity to opt-out of the advanced meter(s) before or after their meter upgrade(s).
CPAU will also be piloting 500 advanced electric residential meters with remote disconnect and
reconnect capability in strategic locations where there is a high rate of turnover (move in/move out),
difficulty of access, and history of non-payment.
Background
On November 19, 2018, the City Council approved the Utilities Smart Grid Assessment and Technology
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Implementation Plan (Staff Report #9780). The assessment recommended the implementation of AMI
and meter data management system (MDMS) smart grid systems for the benefit of electric, natural gas
and water utility customers.
On July 7, 2021, the UAC approved use of the Electric Special Project Reserves in an amount not-to-
exceed $18.5M to fund the Smart Grid Installation Project (EL-11014) (UAC Report #12285). However,
the total project estimate has increased to $18.9M to reflect potential annual CPI index escalator for
installation services of $0.4M post January 1, 2023.
On October 18, 2021, Council approved the AMI contract with Sensus for the citywide AMI system and
installation services (Staff Report #13665). On February 14, 2022, Council approved the MDMS contract
with SmartWorks (Report #13712) to act as the system of record for all meter readings and customer
consumption. It will offer dashboards, visualizations, and analytics to view individual meters or
aggregated meters. The MDMS also provides analysis tools for water leak detection, outage map, and
transformer health.
CPAU has begun a concerted effort to communicate the many facets of this project, including customer
and organization benefits and costs, project timeline and what customers and employees can expect
during different stages of the project, how will this project impact individual staff members, staffing, and
training needs. The AMI project related information can be found at www.cityofpaloalto.org/AMI.
Discussion
Implementing AMI will impact many facets of the CPAU organization and customer interactions. In
addition to early stage communication and feedback from CPAU staff and customers, operational
policies and procedures must be evaluated and updated, with UAC and Council input. Some policies
may not be fully defined until AMI systems are fully configured and business process reengineering are
completed. These discussions will help inform which direction the policies will shift. Any final policies
will be incorporated as revisions to existing Rules and Regulations and presented to Council for approval.
Opt-Out Policy (Electric and Gas)
According to national statistics, CPAU anticipates approximately 0.5% of customers may want to opt out
of the AMI program (150 of 30,000 customers). Customers who opt out will not be able to realize the
benefits of an advanced meter. The electric distribution system is evolving into a complex network that
will allow integration of widely distributed energy resources (DER) such renewable generation, storage,
and energy management systems owned by customers. The widespread adoption of DER requires CPAU
to implement time-dependent electric customer rates, provide more timely and relevant information to
customer about electric consumption patterns, and to gain greater visibility of the electricity flows in the
distribution system for reliable utility operations. The AMI system will also provide greater visibility of
electrical outages and water leaks for customers. AMI sensors will enable faster detection and
restoration of electrical outages and repair of water leaks. AMI will provide tools for customers to
implement additional customer energy efficiency and conservation initiatives.
If a residential customer wishes to opt-out of the AMI electric and/or gas program, they will be given the
opportunity to opt out either before or after their advanced meter upgrade. If the customer would like
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to keep their existing legacy meter, they will have to notify CPAU before their scheduled AMI meter
replacement date. Customers will receive one mailer and one door hanger in advance of their meter
upgrade. If an advanced meter has been installed, CPAU will disable the AMI meter’s radio transmission
communications which also results in a monthly manual meter read for billing purposes. CPAU will not
be providing a water meter opt-out option since water meters are typically located in the public right of
way and distant from the home.
Opt-out customers will be assessed opt-out fees to recover costs for Customer Service, Meter Reading
and Billing for manual monthly billing. A one-time non-refundable set up charge in the amount of $100
will be billed on the customer residential account. In addition, a recurring monthly fee of $25 will be
billed to the residential account to cover the costs of utility billing and manual meter read verification.
Customers can opt-in to the AMI program at any time to discontinue the opt-out fees for no charge.
Electric Meter Remote Disconnect/Reconnect Policy
One major operational benefit of AMI is reducing the cost and number of utility service vehicles being
dispatched (truck roll) for customer disconnection and reconnection. By decreasing the number of truck
rolls, the City’s carbon footprint is also reduced and utility resources can be reassigned to other services.
Remote disconnect meters have a breaker inside of them that can be controlled remotely. This would be
an effective solution for customers who are turned on and off frequently as well as residences that have
a high turnover such as rental properties or apartment complexes. Customer service will also be
enhanced for these high turnover residential properties because remote disconnection and
reconnection can occur within one business day instead of scheduling an appointment for one to three
days out depending on staff’s availability. CPAU can tell our customers with remote
disconnect/reconnect meters exactly when to expect their power to be turned on for move-in day and
shut off on move-out day. For non-payment customers who had been disconnected in accordance with
the process set out in Rule 9, CPAU can restore power almost immediately after payment has been
received instead of waiting for a truck roll.
Timeline
Due to materials shortage and supply chain delays, delivery of electric commercial AMI meters has been
delayed four to six months. The Beta phase (field deployment of ~ 1,000 electric meters) will likely
begin in January 2023 instead of July 2022. The Beta phase is a comprehensive quality assurance effort
including end-to-end system integration, meter functionality, parallel billing, business process
documentation, and training. Tentatively, CPAU expects full AMI deployment to be completed by end of
calendar year 2024.
Policy Implications
A number of policies to implement and operate an AMI system must be considered and approved as the
project implementation progresses. Such policies and procedures and related Utilities Rules and
Regulations will include: opt-out policy (discussed here), meter reading (discussed here), billing
estimation in the event of a communication network outage, billing adjustment for water leak
forgiveness.
Stakeholder Engagement
As part of the 2018 Utilities Strategic Plan development, staff actively engaged with internal and
external stakeholders to identify priorities to be carried out by staff over the next three to five years.
AMI was a recurring theme and identified as a strategic initiative under the “Technology” priority to
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increase system reliability, enhance customer experience, improve response time, and meet the
community’s sustainability goals.
Environmental Review
The Utilities Advisory Commission’s discussion of the AMI policies does not meet the definition of a
project under Public Resources Code 21065 and therefore California Environmental Quality Act (CEQA)
review is not required.
Attachments:
• Attachment A: CPAU OptOut Policy 1.8
• Attachment B: CPAU RemoteDisconnect Policy 1.8
• Attachment C: Rule 09 Discontinuance Restoration - Redline - Draft 5-18-22
• Attachment D: Rule 10 Meter Reading- draft 5-18-22
• Attachment E: Presentation
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POLICY AND PROCEDURES XX
Revised: May 2022
Advanced Metering Infrastructure (AMI) Opt-Out Policy
I.BENEFITS OF ADVANCED METERING
Provides customer with hourly/daily utility usage information to help customer understand
where and when energy and water are being consumed, so customer can make informed
decisions about their utility consumption.
Enables early detection of water leak on property, reducing unexpected high-water bills.
No need to wait for a month to receive a bill and possible surprise at high costs if there has been
a leak or other utility usage spike at their home.
Hassle-free transfer of service; eliminates the need for appointments to turn service on or off.
Faster detection of electrical outages, causes, and shorter restoration time.
Less home and business visits will eliminate manual meter readers, saving time, money, and
meter reader injuries.
AMI data will allow CPAU to make better electric distribution system maintenance decisions.
Enables CPAU to better manage the distribution system, leading to greater reliability.
II.GENERAL POLICY STATEMENTS
Advanced Metering Participation
Unless customer specifically opts out in the advertised opt-out period:
o All customers will be upgraded to advanced metering
o New accounts will automatically participate in advanced metering
If customer wishes to opt out and temporarily keep their existing (legacy) meter, customer must
notify the City of Palo Alto before a new AMI-enabled meter is installed. Customer will be
notified of scheduled meter replacement via mailer and door hanger. If customer contacts the
City of Palo Alto after the AMI meter is installed, the AMI meter’s radio transmission
communications will be turned off and disabled remotely, and meters will be read manually.
All legacy meters will be upgraded to a new AMI-enabled meter with radio turned off upon:
o Legacy meter failure
o Meter maintenance/obsolescence
o Customer decision to upgrade
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POLICY AND PROCEDURES XX
Revised: May 2022
III.ELIGIBLE CUSTOMERS
Customers selecting to opt out of AMI (either with legacy meter or inactive AMI meter)must
participate in the “Customer Reads Own Meter” program.
Customer must sign a form acknowledging fees, terms, and conditions of the “Customer Reads
Own Meter” program.
As part of the “Customer Reads Own Meter” program, customer must provide access for CPAU to
read the meters for verification on an annual basis. For such purposes,Customer must provide
meter access to CPAU personnel during regular business hours.
Customer must opt out at the account level, and the opt out must be completed by the account
holder.
Customer will be ineligible to opt out or opt-out selection will be revoked if a customer has a record of
any of the following:
Equipment tampering or electric/water/gas diversion
Account is not current, not in good standing,or not in compliance with rules and regulations
Obstructed meter access for meter reading and/or meter maintenance
A meter site location that CPAU deemed inaccessible or hazardous for City of Palo Alto personnel
to access.
Customer Type Eligible to Opt-Out
Residential: Single Family
Electric Service
Gas Service
Water Service
Yes
Yes
No*
Move-in, New Account, New Service No
Residential: Multi-unit No
Commercial & Industrial No
Net Metering (solar)No
Temporary Service No
*CPAU will not be providing a water meter opt-out option since water meters are typically located in the public
right of way, not on private property.
IV.OPT-OUT FEE
1.Set Up Charge
Set up charge is per residence, not per meter. If customer has both an electric and gas meter at
their property, only one setup charge will be added to the statement. However, if customer
would like to opt-out for other residences on their account, there is a setup charge for each
additional location.
Legacy electric/gas meters: A one-time non-refundable set up charge in the amount of
$100 will be billed on the residential customer account.
Customer can keep their existing legacy meter until the opt out period expires
5.a
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POLICY AND PROCEDURES XX
Revised: May 2022
Meter Reading
o Customer will be required to participate in the CPAU “Customer Reads Own
Meter” program. This program allows customer to read (or photograph) their
own meter and submit that information to CPAU on a monthly basis.
o Submit Reads:
Email: meter.readings@cityofpaloalto.org
Mail pre printed Meter Read Cards:
City of Palo Alto Utilities,Ground Floor
Palo Alto, CA 94301
Online, through the Meter Reading Form
2.Monthly Fees:
In addition to the applicable monthly Customer Charge for service, a non-refundable
monthly fee in the amount of $25 will be billed to the residential account. The fee will
cover the expense of processing customer self reads.
Customers can opt in to AMI at any time for no charge.
V.HOW TO OPT-OUT
For customer’s convenience, there are multiple ways to opt out of the advanced meter program.
•Use the online form.
•Submit an opt-out request by visiting our office, City of Palo Alto Utilities Ground Floor, 250
Hamilton Ave, Palo Alto CA 94301.
• By phone,by calling at (650) 329-2161.
VI.“CUSTOMER READS OWN METER” PROGRAM (RULE AND REGULATION 10)
The “Customer Reads Own Meter” program allows Customers to be responsible for reading CPAU Meters
located on their property. The Customer sends the Meter readings to CPAU for entry into CPAU’s
computer billing system. It is the Customer’s responsibility to furnish the readings to CPAU in accordance
with the Meter reading schedule that CPAU will provide upon the Customer’s entry into the program.
Customer participation in this program is at the sole discretion of CPAU.
1.If a Customer reading is not received by CPAU in time for billing, an estimated read(s) will be
made by CPAU. Failure by the Customer to consistently provide Meter readings shall result in
termination of participation of both “Customer Reads Own Meter” and “Opt-Out” programs.
2.In the event the Customer fails to provide readings for two consecutive months, CPAU may
require the Customer to provide access to the Meters, or relocate them, at the Customer’s
expense, to an accessible location on the property, in accordance with such CPAU Rules and
Regulations, procedures, and standards that apply to relocation of Service.
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POLICY AND PROCEDURES XX
Revised: May 2022
3.On an annual basis, CPAU will read the Meters for verification. For such purposes, Meter access
by CPAU personnel during regular business hours must be provided by the Customer.
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ELECTRIC METER REMOTE DISCONNECT/RECONNECT POLICY XX
Revised: May 2022
Electric Meter Remote Disconnect/Reconnect Policy
This policy outlines how City of Palo Alto Utilities will use the remote disconnect reconnect enabled
electric meter function for customer electric services. The use of remote disconnect reconnect electric
meters allows for the disconnection and/or reconnection of an electrical service to a service address
without City of Palo Alto staff being physically present where the electric meter is located.
I.INSTALLATION:
Remote disconnect reconnect enabled electric meters may be installed at any location identified by City
of Palo Alto Utilities using the following conditions as guidelines.
•A service address that has a high rate of move-in and move-out events, where multiple accounts
are opened and closed within a 36-month span.
•Any service address that has been physically disconnected for non-payment more than 1 time in
the previous 12 months.
•A meter site location is deemed inaccessible or hazardous for City of Palo Alto personnel to
access.
II.DISCONNECTION:
City of Palo Alto reserves the right to remotely disconnect the electric meter in accordance with Rule 9
(Disconnection, Termination, and Restoration of Service) if an account has been closed for move out, if
there is an outstanding bill that has no agreed upon resolution, or if a hazardous condition has been
identified. Customer is fully responsible for any impacts resulting from the disconnection at the service
address.
III.RECONNECTION:
Upon customer resolving a Customer Service Department-related issue such as establishing a new
account or making an overdue payment, City of Palo Alto will remotely reconnect the electric services by
initializing the reconnection switch in the meter for the service address within 1 full business day. City of
Palo Alto reserves the right to remotely reconnect the electric meter and it is the customer’s full
responsibility to ensure that all equipment and appliances at the service address pose no potential
hazard if and when the electric meter is reconnected, and the electric service is restored.
Attachment B
•
CITY OF
PALO ALTO
UTILITIES
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 1
A. CUSTOMER-INITIATED TERMINATION OF UTILITY SERVICE
1.A Customer requesting termination of Utility Service(s) must notify the CPAU Customer
Service Office at least three business days before the Service termination effective
date. Upon receipt of such notice, CPAU has no obligation to render Service after the
effective date of such change, and CPAU will discontinue the Customer’s
responsibility for bills for Service supplied to the Premises after that date.
2.A Customer vacating a Premise to move to another Premise served by CPAU, but
wishing Service to continue beyond the date vacated, must provide an effective date
of termination to the CPAU Office or Call Center at the time of the request for
establishment of Service for the new Premise. The Customer is financially
responsible for all Service supplied prior to the Service end date, and Customer must
provide a forwarding address for final billing purposes.
B.CPAU-INITIATED TERMINATION OR DISCONNECTION OF SERVICE
CPAU may terminate or disconnect Utility Service when an existing Customer, through action or
inaction, has not complied with Utility Service requirements as stated in these Rules and
Regulations, or other applicable laws. CPAU will terminate or disconnect Utility Service as a last
resort. Actions that warrant termination or disconnection of Service include, but are not limited
to, the following:
1.Use of Utility Services without having first complied with the requirements for Service.
Customers will be responsible for all associated Charges from the date of initial
Service as determined by CPAU, up to the maximum period allowed by law.
2.Vacating Premises without notification to CPAU.
3.Tampering, damaging, interfering with or destroying CPAU equipment, facilities or
property. Customers will be liable for all damage to CPAU arising from negligence,
lack of proper care, or wrongful act of the Customer or Customer’s tenants, agents,
employees or contractors.
Attachment C 5.c
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 2
4. Nonpayment of bills or any proper Charges from special fees, licensing agreements, loans
or returned check(s) due to insufficient funds in Customer’s bank account; failure to
establish credit, failure to provide adequate credit information, or failure to provide
required deposits.
C. PROCEDURES FOR CPAU-INITIATED DISCONNECTION OF SERVICE
1. Prior to disconnection for non-payment, CPAU will provide two written notices to the
Customer, and/or the third party the Customer has designated to receive such notices,
as applicable:
a. 10-Day Late Notice: The first “Late Notice” is issued 5 days after the bill due date
and informs Customer that a late fee has been charged, and Customer must pay
the overdue amount by the date specified to avoid disconnection of Service.
b. 48-Hour Disconnect Notice: If payment is not received by the date specified in
the 10-day notice, a Disconnect Notice will be delivered to the Customer’s
Premises, notifying the Customer that payment must be received within 48 hours
or Utilities Services will be disconnected for non-payment. If payment is not
received within the 48-hour period, Utilities Services may be disconnected
without further notice.
The 48-hour Disconnect Notice will include:
(1) The name and address of the Customer whose Account is delinquent.
(2) The amount of the delinquency and late fee.
(3) The date by which payment or arrangements for payment is required to avoid
disconnection of Service.
(4) The procedure by which the Customer may initiate a complaint or request an
investigation concerning Service or Charges; except that, if the bill for Service
contains a description of that procedure, the notice is not required to contain
that information.
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 3
(5) The procedure by which the Customer may request amortization of the unpaid
Charges.
(6) The procedure for the Customer to obtain information on the availability of
financial assistance, including private, local, state, or federal sources, if
applicable.
(7) The telephone number of a representative of CPAU who can provide
additional information or institute arrangements for payment.
2. Customers may contact CPAU Customer Service Center to discuss options for averting
disconnection of Service for non-payment:
IN PERSON
City of Palo Alto Utilities
Customer Service Center, Ground Floor
250 Hamilton Avenue
Palo Alto, CA 94301
PHONE: 650-329-2161
BY MAIL
City of Palo Alto Utilities
Customer Service Center
PO Box 10250
Palo Alto, CA 94303
BY E-MAIL
UtilitiesCustomerService@cityofpaloalto.org
3. Deferred or Reduced Payments Policy: Customers may contact CPAU Customer Service
Center to request deferred or reduced payments based on Customer’s demonstrated
financial need. CPAU will notify the Customer in writing of the terms of deferred or
reduced payment.
4. Alternative Payment Schedule Policy: Customers may contact CPAU Customer Service
Center to request an alternative payment schedule based on Customer’s demonstrated
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 4
financial need. An example of a possible alternative payment schedule is the Budget
Billing Payment Plan (BBPP) found in Rule and Regulation 11, “Billing, Adjustment
and Payment of Bills.” CPAU will notify the Customer in writing of the terms of the
alternative payment schedule.
5. To avoid disconnection of Utility Service, a Customer’s outstanding Account balance
may be transferred to another Account in the same class of Service in that Customer’s
name at another location served by CPAU.
6. To avoid disconnection of Utility Service, CPAU may extend payment arrangements for
the unpaid Account balance to accommodate a Customer’s financial situation. If the
Customer fails to meet the terms of the payment arrangement, the outstanding balance
will become immediately due and payable, and the Account Service(s) will be subject
to disconnection after expiration of a 48-hour Disconnect Notice.
7. Customers whose Utility Service has been disconnected for non-payment will have their
Accounts referred to a collection agency when past-due balances exceed 180 calendar
days.
8. Residential metered Utility Services will not be disconnected for non-payment of a bill
on any Friday, Saturday, Sunday, legal holiday or at any time during which the
Utilities Customer Service Office or Call Center is closed. Online payments may take
up to 24 hours to be received by CPAU.
9. Utility Service will not be disconnected for non-payment of an incorrect bill until the
corrected bill becomes past due.
10. CPAU’s Disputed Bills Policy can be found in Rule and Regulation 11, “Billing,
Adjustment, and Payment of Bills.”
11. Utility Service will not be disconnected for non-payment of a disputed bill during
investigation or review by CPAU. The non-disputed portion of the Utility bill will
remain due and payable. CPAU findings and resolution of a disputed bill will be
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 5
communicated to the Customer within thirty calendar days of the Customer’s
notification to CPAU of the bill dispute.
12. Customers in need of assistance with bill payment for their Utility Service, due to a
reduction in household income resulting from a member of the household being
called to active duty status in the military, may apply for shut-off and payment
protections for a period of 180 days, pursuant to the California Military and Veterans
Code, Section 827, as amended. CPAU, at its option, may extend these protections for
an additional 180 days.
D. PRIOR NOTICE EXCUSED IN CERTAIN SITUATIONS
CPAU may immediately terminate Utility Services, without notice, for an unauthorized action of
a Customer, including, but not limited to:
1. Theft of Utility Service.
2. Willful waste of Water.
3. Unsafe wiring or equipment on Customer Premises or wiring or equipment that fails to
meet CPAU standards or applicable law. CPAU reserves the right to inspect if CPAU
staff reasonably believes that unsafe conditions exist. If the Customer discovers any
defect in their Utility Service, the Customer must notify CPAU immediately.
4. Use of Customer equipment that imposes an electrical Load adversely affecting CPAU’s
Distribution System operation, Service capacity, or Service to its other Customers.
Any Customer that operates Electric equipment including, but not limited to, pumps,
welders, furnaces, compressors or other equipment where the use of Electricity is
intermittent, and causes significant voltage fluctuations or electromagnetic
interference to other Customers, must reasonably limit such impacts or interference
upon request by CPAU. The Customer may be required to permanently mitigate any
ongoing disruption to the Electric Distribution System to an acceptable level
established by CPAU, or avoid the use of such equipment. Failure to comply with
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 6
such mitigation and/or limitation requests may result in immediate termination of
Utility Service.
5. Placement, construction, or maintenance of any structure, vegetation, debris, or other
object upon the Customer’s Premises that, in CPAU’s judgment, endangers the safe
and reliable operation or maintenance of CPAU overhead or underground Electrical,
Fiber Optic, Water, Gas and Wastewater facilities.
E. REMOTE DISCONNECT/RECONNECT
CPAU will use the remote disconnect reconnect enabled electric meter function for Customer
electric meters on Customer electric services. The use of remote disconnect reconnect electric
meters allows for the disconnection and/or reconnection of an electrical service to a service
address without CPAU staff being physically present where the electric meter is located. Remote
disconnect reconnect enabled electric meters may be installed at any location identified by
CPAU using the following conditions as guidelines.
• A service address that has a high rate of move-in and move-out events where multiple accounts
are opened and closed within a 36-month span.
• Any service address that has been physically disconnected for non-payment more than 1 time in
the previous 12 months.
• A meter site location is deemed inaccessible or hazardous for CPAU personnel to access.
1. Disconnect. CPAU reserves the right to remotely disconnect the electric meter if an account has
been closed for move out, if there is an outstanding bill that has no agreed upon resolution, or if a
hazardous condition has been identified. Customer is fully responsible for any impacts resulting
from the disconnection at the service address.
2. Reconnection. Upon customer resolving a Customer Service Department-related issue such as
establishing a new account or making an overdue payment, CPAU will remotely reconnect the
electric services by initializing the reconnection switch in the meter for the service address within
1 full business day. CPAU reserves the right to remotely reconnect the electric meter and it is the
customer’s full responsibility to ensure that all equipment and appliances at the service address
pose no potential hazard if and when the electric meter is reconnected and the electric service is
restored.
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DISCONNECTION, TERMINATION AND RESTORATION OF SERVICE
RULE AND REGULATION 9
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective 10-21-2019 TBD
Sheet No 7
E.F. RESTORATION OF SERVICE
1. CPAU will restore Service to a disconnected Account when the financial cause for
disconnection has been rectified and Customer has paid all proper Charges due,
including any additional deposits or reconnection Charges.
2. CPAU will restore Service to a terminated Account when it determines that the physical
cause for termination has been rectified, safe operating conditions have been restored,
and the engineering and operations requirements for Service have been met, including
compliance with CPAU Rules and Regulations.
(END)
5.c
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METER READING
RULE AND REGULATION 10
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective TBD6-27-2016
Sheet No. 1
A.BILLING PERIOD
1.CPAU will attempt to read Water, Gas, and Electric Meters at consistent intervals ranging
from 27-33 days for each Billing Period.
2.Under normal conditions, bills will be based upon actual Meter readings. Under abnormal
conditions, such as, but not limited to Meter malfunction, lack of access to the Meter, or
CPAU staffing limitations, the bill for a Billing Period may be based upon estimated Meter
readings taken from the historical record of consumption at the Premises. To correct any
inaccuracies arising from the use of an estimated Meter reading, CPAU will make
reasonable efforts, but does not guarantee, that it will obtain a Meter reading for the
following Billing Period based on an actual Meter reading.
3.CPAU may estimate bills for unmetered Utility Service, for Utility Service from Meters
which have been tampered with, or where access has been denied or impeded by the
Customer, by the best available means, which may include, but are not limited to:
estimation by comparison to prior Billing Period for the same Premise and equivalent
Billing Period for the prior year. Such bills shall be due and payable by the Customer.
4. When the estimated Meter reading is higher than the actual Meter reading, adjustments for
consumption and cost will be made to the Customer’s next regularly scheduled bill.
B. MULTIPLE METERS FOR SAME SERVICE
For the purpose of calculating Charges, each Meter on the Customer’s Premises will be considered
separately, and the readings of two or more Meters will not be combined, except as follows:
1.Where combinations of Meter Readings are specifically provided for in Rate Schedules or
via contract with the Customer;
2.Where CPAU’s operating convenience or necessity requires the installation of two or more
Meters on the Customer’s Premises.
Attachment D
5.d
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METER READING
RULE AND REGULATION 10
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective TBD6-27-2016
Sheet No. 2
C. “CUSTOMER READS OWN METER” PROGRAM
The “Customer Reads Own Meter” program allows Customers to be responsible for the reading of
CPAU Meters located on their property. The Customer sends the Meter readings to CPAU for
entry into CPAU’s computer billing system. It is the Customer’s responsibility to furnish the
readings to CPAU in accordance with the Meter reading schedule that CPAU will provide upon
the Customer’s entry into the program. Customer participation in this program is at the sole
discretion of CPAU.
1. If a Customer reading is not received by CPAU in time for billing, an estimated read(s)
will be made by CPAU. Failure by the Customer to consistently provide Meter readings
shall result in termination of participation in the “Customer Reads Own Meter” program.
2. In the event the Customer fails to provide readings for two consecutive months, CPAU
may require the Customer to provide access to the Meters, or relocate them, at the
Customer’s expense, to an accessible location on the property, in accordance with such
CPAU Rules and Regulations, procedures, and standards that apply to relocation of
Service.
3. On an annual basis, CPAU will read the Meters for verification. For such purposes, Meter
access by CPAU personnel at reasonable hours must be provided by the Customer.
D. OPT-OUT OF ADVANCED METERING
Customer may choose to opt out and temporarily keep their existing (legacy) meter by notifying
CPAU before a new AMI-enabled meter is installed. If Customer contacts the CPAU after the
AMI meter is installed, the AMI meter’s radio transmission communications will be turned off and
disabled remotely, and meters will be read manually.
Unless customer specifically opts out in the advertised opt-out period:
All customers will be upgraded to advanced metering
New accounts will automatically participate in advanced metering
5.d
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METER READING
RULE AND REGULATION 10
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective TBD6-27-2016
Sheet No. 3
1. Eligible Customers
Customers selecting to opt out of AMI (either with legacy meter or inactive AMI meter)
must participate in the “Customer Reads Own Meter” program.
Customer must sign a form acknowledging fees, terms, and conditions of the “Customer
Reads Own Meter” program.
As part of the “Customer Reads Own Meter” program, customer must provide access for
CPAU to read the meters for verification on an annual basis. For such purposes,
Customer must provide meter access to CPAU personnel during regular business hours.
Customer must opt out at the account level, and the opt out must be completed by the
account holder.
2. Ineligible Customers
Customer will be ineligible to opt out or opt-out selection will be revoked if a customer
has a record of any of the following:
Equipment tampering or electric/water/gas diversion
Account is not current, not in good standing, or not in compliance with rules and
regulations
Obstructed meter access for meter reading and/or meter maintenance
A meter site location that CPAU deemed inaccessible or hazardous for City of Palo Alto
personnel to access.
3. Opt-out Fee
a. Set Up Charge. The set up charge is per residence, not per meter. If Customer has both an
electric and gas meter at their property, only one setup charge will be added to the
statement. However, if Customer would like to opt-out for other residences on their
account, there is a setup charge for each additional location.
Legacy electric/gas meters: A one-time non-refundable set up charge in the
amount of $100 will be billed on the residential customer account.
Customer can keep their existing legacy meter until the opt out period expires
5.d
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METER READING
RULE AND REGULATION 10
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective TBD6-27-2016
Sheet No. 4
Meter Reading
Customer will be required to participate in the CPAU “Customer Reads Own Meter”
program. This program allows customer to read (or photograph) their own meter and
submit that information to CPAU on a monthly basis.
Submit Reads:
Email: meter.readings@cityofpaloalto.org
Mail pre printed Meter Read Cards:
City of Palo Alto Utilities, Ground Floor
Palo Alto, CA 94301
Online, through the Meter Reading Form
b. Monthly Fees. In addition to the applicable monthly Customer Charge for service, a non-
refundable monthly fee in the amount of $25 will be billed to the residential account. The
fee will cover the expense of processing customer self reads.
There is no fee to opt in to AMI.
4. How to Opt-out
For Customer’s convenience, there are multiple ways to opt out of the advanced meter
program.
• Use the online form.
• Submit an opt-out request by visiting our office, City of Palo Alto Utilities
Ground Floor, 250 Hamilton Ave, Palo Alto CA 94301.
• By phone, by calling at (650) 329-2161.
5.d
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METER READING
RULE AND REGULATION 10
CITY OF PALO ALTO
UTILITIES RULES AND REGULATIONS
Issued by the City Council
Effective TBD6-27-2016
Sheet No. 5
D. METER READING ERRORS
Under certain circumstances, CPAU will adjust a Customer’s bill for reasons of accuracy. (See
CPAU Rule 11 regarding billing adjustments related to error or malfunction.)
1. Meter reading errors may be brought to the attention of CPAU by the Customer or
identified by a computer generated report as part of the billing review process.
2. When a Meter reading error has been identified, the Customer will be notified of the
correction within 30 calendar days.
(END)
5.d
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JUNE 8, 2022 www.cityofpaloalto.org
Advanced Metering Infrastructure (AMI)
Customer Opt-Out and
Remote Disconnect/Reconnect
Po licies
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Opt-Out Policy
JUNE 8, 2022 www.cityofpaloalto.org
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1
Why and Opt-Out Policy?
Purpose:
•Provide customers an alternative to a standard advanced meter
installation
•Anticipate and prepare for a small group of concerned customers’ needs
Core Principles:
•Allow customers an equitable choice of service, while meeting utility
equipment requirements
•Educate customers on the benefits of an advanced meter
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2
General Opt-Out Policy
•If customer wishes to opt out and temporarily keep their existing (legacy) meter,
customer must notify the City of Palo Alto before a new AMI-enabled meter is
installed. Customer will be notified of scheduled meter replacement via mailer
and door hanger.
•Unless customer specifically opts out in the advertised opt-out period:
•All customers will be upgraded to advanced metering
•New accounts will automatically participate in advanced metering
•If customer contacts the City of Palo Alto after the AMI meter is installed, the
AMI meter ’s radio transmission communications will be turned off and disabled
remotely, and meters will be read manually.
•All legacy meters will be upgraded to a new AMI-enabled meter with radio
turned off upon:
•Legacy meter failure
•Meter maintenance/obsolescence
•Customer decision to upgrade
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3
Eligible Customers
•Customers selecting to opt out of AMI (either with legacy meter or inactive AMI
meter) must participate in the “Customer Reads Own Meter ” program.
•Customer must sign a form acknowledging fees, terms, and conditions of the
“Customer Reads Own Meter ” program.
•As part of the “Customer Reads Own Meter ” program, customer must provide
access for CPAU to read the meters for verification on an annual basis. For such
purposes, customer must provide meter access to CPAU personnel during regular
business hours.
•Customer must opt out at the account level, and the opt out must be completed
by the account holder.
5.e
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Ineligible Customers
Customer will be ineligible to opt out or opt-out selection will be revoked if a customer has a
record of any of the following:
•Equipment tampering or electric/water/gas diversion
•Account is not current, not in good standing, or not in compliance with rules and regulations
•Obstructed meter access for meter reading and/or meter maintenance
•A meter site location that CPAU deemed inaccessible or hazardous for City of Palo Alto personnel to
access.
4
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Opt-Out Fee
1.Set Up Charge
Set up charge is per residence, not per meter. If customer has both an electric and gas meter at their property, only one setup charge will be
added to the statement. However, if customer would like to opt-out for other residences on their account, there is a setup charge for each
additional location.
•Legacy electric/gas meters: A one-time non-refundable set up charge in the amount of $100 will be billed on the residential customer
account.
•Meter Reading
•Customer will be required to participate in the CPAU “Customer Reads Own Meter ” program. This program allows customer to
read (or photograph) their own meter and submit that information to CPAU on a monthly basis.
2.Monthly Fees:
•In addition to the applicable monthly Customer Charge for service, a non-refundable monthly fee in the amount of $25 will be billed
to the residential account. The fee will cover the expense of processing customer self reads.
Customers can opt-in at any time for no charge.
5
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Re mote Disconnect / Re connect
JUNE 8, 2022 www.cityofpaloalto.org
5.e
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6
Electric Meter Remote Disconnect/Reconnect
•This policy outlines how City of Palo Alto Utilities will use the remote
disconnect reconnect enabled electric meter function for customer
electric services.
•The use of remote disconnect reconnect electric meters allows for the
disconnection and/or reconnection of an electrical service to a service
address without City of Palo Alto staff being physically present where
the electric meter is located.
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7
Installation
Remote disconnect reconnect enabled electric meters may be installed at any
location identified by City of Palo Alto Utilities using the following conditions
as guidelines.
•A service address that has a high rate of move-in and move-out events,
where multiple accounts are opened and closed within a 36-month span.
•Any service address that has been physically disconnected for non-
payment more than 1 time in the previous 12 months.
•A meter site location is deemed inaccessible or hazardous for City of Palo
Alto personnel to access.
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8
Disconnection
•City of Palo Alto reserves the right to remotely disconnect
the electric meter in accordance with Rule 9 (Disconnection,
Te rmination, and Restoration of Service) if an account has
been closed for move out, if there is an outstanding bill that
has no agreed upon resolution, or if a hazardous condition
has been identified.
•Customer is fully responsible for any impacts resulting from
the disconnection at the service address.
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9
Reconnection
•Upon customer resolving a Customer Service Department-
related issue such as establishing a new account or making
an overdue payment, City of Palo Alto will remotely
reconnect the electric services by initializing the
reconnection switch in the meter for the service address
within 1 full business day.
•City of Palo Alto reserves the right to remotely reconnect the
electric meter and it is the customer ’s full responsibility to
ensure that all equipment and appliances at the service
address pose no potential hazard if and when the electric
meter is reconnected, and the electric service is restored.
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City of Palo Alto (ID # 14201)
Utilities Advisory Commission Staff Report
Meeting Date: 6/8/2022 Report Type:
City of Palo Alto Page 1
Title: Informational Update on Utilities' Quarterly Financial Report for Q2 of
FY2022
From: Director of Utilities
Lead Department: Utilities
Recommendation
This report is for information only. No action is required.
Executive Summary
Attached are the Q2 Fiscal Year (FY) 2022 financial results for the City’s electric, gas,
wastewater, water, and fiber utilities (Attachment A). This report on the utility financial
positions is released when the City closes its accounting books for the quarter, which occurs
after income and expenses are reconciled.
Items of special interest in this report are summarized below:
Electric Utility
Sales for FY 2022 are expected to be 3.8% lower than projected in the FY 2022 Financial Plan
due to residential electric use making up a larger share of revenue than commercial use, as
compared to typical pre- pandemic levels. Expenses are expected to be higher than projected
due to poor hydroelectric conditions. Electric Reserves are expected to be within guideline
ranges at year end. Implementation of the Hydro rate Adjuster will help mitigate higher costs.
Gas Utility
Sales are expected to be 1.5% higher than projected in the FY 2022 Financial Plan. Expenses
have increased due to rising natural gas market prices, however, those higher market prices are
passed through to customers each month. The Gas Operations Reserve is expected to be near
the target level at year end. In addition, $2.3 million was moved to a Cap and Trade reserve to
separate it from the Operations Reserves.
Water Utility
Water sales, revenue, and costs are expected to be lower than expected due to drought-related
conservation. Water Operations Reserves Plan. Reservoir work and water main replacement
projects have required increased funding. The Water Operations Reserve is expected to be
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City of Palo Alto Page 2
within the guideline range by the end of FY 2023.
Wastewater Collection Utility
Wastewater revenues are expected to be 3.1% lower than projected in the FY 202 2 Financial
Plan due to the effects of the pandemic. Expenses are expected to be 2.4% higher than forecast
due to increases in salaries and benefits. The Wastewater Collection Operations Reserve is
projected to be below the target guideline at year end.
Fiber Optic Utility
Fiber revenues are projected to be $3.7 million or 14% lower than FY 2022 forecast of $4.3M
due to consolidation and closure of businesses during the pandemic. The Fiber Network Rebuild
CIP project has been placed on hold pending results of the engineering designs by Magellan .
Most of the consulting work will be completed in FY 2022. The Fiber Optic Utility Rate
Stabilization Reserve is expected to remain unchanged at $33.3 million at the end of FY 2022.
Attachments:
• Attachment A: FY22-Q2 Financial Report
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Utilities Quarterly
Financial Update
Second Quarter of Fiscal Year 2022
June 2022
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Utilities Quarterly Financial Update
Second Quarter of FY 2022
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Table of Contents
Utility Financial Summary ...................................................................................................... 2
Electric Utility Overview ................................................................................................................................ 2
Gas Utility Overview...................................................................................................................................... 2
Wastewater Collection Utility Overview ....................................................................................................... 3
Fiber Optic Utility Overview .......................................................................................................................... 3
Residential Bill Comparisons ......................................................................................................................... 6
List of Tables
Table 1: Utilities Financials, FY 2022 Projected ............................................................................................ 5
Table 2: Operations Reserves, FY 2022 Projected ($,000) ............................................................................ 5
Table 3: Residential Electric Bill Comparison ($/month) .............................................................................. 6
Table 4: Residential Natural Gas Bill Comparison ($/month) ....................................................................... 6
Table 5: Residential Water Bill Comparison ($/month) ................................................................................ 6
Table 6: Residential Wastewater Collection (Sewer) Bill Comparison ($/month) ........................................ 6
Table 7: Median Residential Overall Bill Comparison ($/month) ................................................................. 7
Table 8: FY 2022 Q2 Utilities Fund Reserve Report (‘000) ............................................................................ 8
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June 2022
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Utility Financial Summary
This section describes the unaudited actual financial results for the second quarter of fiscal year (FY) 2022 1 for
all Utilities funds. The Council-adopted long-term Financial Plans for the Electric, Gas, and Water Funds and the
Financial Plan for the Wastewater Collection Fund for FY 2021 – FY 2022 during the budget review process.
Electric Utility Overview
Total electric sales volume projected at the end of FY 2022 is 0.7% lower than sales volume forecasted in the FY
2022 Financial Plan. Sales revenue is projected to be lower by $6.6 million, or 3.8%. The difference between unit
sales and revenues lies in Covid-related customer class shifts, with residential use now accounting for a larger
share of sales than before the pandemic. Expenses are expected to be about $10 million, or 6.1% higher than
forecasted in the FY 2022 Financial Plan. This is mainly due to increases in electric supply purchase costs resulting
from both higher sales and poorer hydro conditions.
The Electric Operations Reserves are projected to remain within guideline ranges through FY 2022 but were low
at the end of FY 2021. Because of this, staff did not make the projected $1 million repayment of a 2018 short
term $10 million loan from the Electric Special Projects (ESP) reserve ($5 million outstanding). In anticipation of
continued dry conditions, $4 million was moved to the Hydro Stabilization Reserve. Due to the very poor hydro
conditions in California and projected higher electric purchase cost, up to $15 million of the available Hydro
Stabilization Reserve may be used to help offset costs. Council approved implementing the Hydro Rate adjuster
mechanism at the $0.013/kwh level effective April 1, 2022.
The Electric Utility CIP Reappropriation and Commitment Reserves totaled a projected $30.1 million at the end
of Q2 FY 2022.
Gas Utility Overview
Gas sales volume is projected to be 1.5% higher at the end of FY 2022 than forecasted in the FY 2022 Financial
Plan. Sales revenue is projected to be higher by $2.9 million or 6.6%, mostly due to higher than expected gas
market commodity prices, but this revenue is offset by higher expenses due to gas commodity purchase costs.
These costs are passed through directly on customer bills, which do not impact reserves. Non-supply costs were
$550k lower, primarily the result of lower than projected administrative costs.
The Gas Operations Reserve was near the target level at the end of FY 2021 and is projected to remain within
guideline ranges during FY 2022. In addition, $2.3 million was moved to a Cap and Trade reserve in FY 2021 to
separate it from the Operations Reserves. These funds are restricted for carbon reduction efforts per AB32. The
Gas Utility CIP Re-appropriation and Commitment Reserves totaled $3.8 million at the end of Q2 FY 2022.
Water Utility Overview
Total water sales volume projected for FY 2022 is 4.2% lower than forecasted in the FY 2022 Financial Plan due
to the water supply emergency declared by SFPUC, ongoing record dry conditions, and the voluntary water use
reductions projected for the upcoming irrigation season. Sales revenue is similarly expected to be 4.8% lower
1 Fiscal Year 2022 runs from July 2021 to June 2022
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June 2022
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than forecasted in the FY 2022 Financial Plan. Staff projects water purchase costs to be 5% lower than forecasted
in the FY 2022 Financial Plan. Staff projects operating expenses other than water purchases and CIP to be 2%
higher than forecasted in the FY 2022 Financial Plan primarily as a result of increases in salaries and benefits and
rent. However, a one-time $5 million transfer from the Operations Reserve to the CIP Reserve that the FY 2022
Financial Plan forecasted to be needed in FY 2022 is no longer expected to be needed due to updated CIP
forecast.
The Water Operations Reserve was above the reserve guideline levels at the end of FY 2021 and is within
guideline levels at the end of Q2, FY2022. The Operations Reserve level dropped $9.5 million during Q1 and Q2
of FY 2022 in part due to anticipated CIP funding needs. This can be seen by the increase in CIP
Reappropriations/Commitments reserves of $11.8 million during the same time period, bringing the projected
end of FY 2022 CIP Reappropriations/Commitments Reserve to $21.9 million. Capital funding needs in FY 2022
are primarily for the ongoing seismic reservoir replacement estimated at $6.6 million in FY 2022 and Water Main
Replacement 28 estimated at $10.8 million in FY 2022. Staff projects the Operations Reserve to return to levels
above the reserve guideline at the end of FY 2022 as construction on Water Main Replacement 28 continues
into FY 2023. Reserve transfers together with expected revenues and expenses are projected to bring the
Operations Reserve to approximately target levels by the end of FY 2023. The need for further transfers will be
re-evaluated at the end of FY 2022 when the year-end reserve balances are known.
Wastewater Collection Utility Overview
Wastewater revenues for FY 2022 are projected to be 3.1% lower than forecasted in the FY 2022 Financial Plan.
This is, in part, due to expected reductions in non-residential sewer usage due to the impacts of the COVID-19
pandemic and lower expected connection and capacity fees and interest income. Wastewater expenses are
projected to be 2.4% higher than projected in the FY 2022 Financial Plan. Although treatment costs were
approximately $0.2 million lower than forecasted in the FY 2022, Financial Plan operations costs such as salaries
and benefits are expected to be approximately $0.7 million higher. The expense comparison in Table 1 includes
the $2.2 million transfer from the Operations Reserve to the Capital Reserve in the actual expenses for FY 2022.
The Wastewater Collection Operations Reserve was within the guideline range at the end of FY 2021 and
dropped below the minimum guideline level of $4.1 million at the end of Q2, FY 2022. This is because funds
were transferred to the CIP Reappropriations/Commitments reserve during Q1 and Q2, primarily to fund
Sanitary Sewer Main Replacement 30 (SSR 30).. SSR 30 was approved by Council on December 13, 2021 and is
scheduled to begin in FY 2022 with a total cost of $4.6 million. Correspondingly, the Wastewater Collection CIP
Reappropriation and Commitment Reserves increased by $4.3 million, bringing the total CIP Reappropriation
and Commitment Reserves to nearly $6 million at the end of Q2, FY 2022. At year end FY 2022, if the projected
Operations Reserve remains below guideline levels due to the CIP needs of the Collection system, Staff will
request Council authorization to transfer funds from the CIP Reserve to replenish the Operations Reserve.
Fiber Optic Utility Overview
Total fiber retail revenues for FY 2022 are projected to be $3.7 million or 14% lower than FY 2022 forecast of
$4.3M due to consolidation and closure of businesses during the pandemic. Even though the City has received
an uptick of new dark fiber service connections, new revenue only partially offsets the high number of
disconnections in FY 2021. Other revenues were $0.1 million lower than projected due to lower than projected
interest income. Fiber expenses were 10% or $0.6 million lower than forecast due to lower than projected
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administrative and capital costs. The projected ending FY 2022 Fiber Optic Utility Rate Stabilization Reserve is
expected to remain the same at $33.3 million. In FY 2021, $2.4 million was encumbered for the Magellan
contract to complete the network engineering designs for the City backbone and FTTH, community engagement,
and updated FTTH business plan. The majority of the consulting work will be completed in FY 2022.
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June 2022
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Table 1: Utilities Financials, FY 2022 Projected
Sales Volumes
Revenue
$,000
Expense
$,000
Net Reserve Change
$,000
Electric Utility
FY 2022 Financial Plan 812,790 MWh 173,486 (188,797) (15,311)
FY 2022 Projected 807,182 MWh 166,853 (199,134) (32,281)
Change from Financial Plan (5,608 MWh)
(0.7%)
(6,633)
(3.8%)
(10,337)
5.5%
(16,970)
Gas Utility
FY 2022 Financial Plan 25,426,000 Therms 43,856 (44,292) (436)
FY 2022 Projected 25,813,000 Therms 46,731 (47,357) (626)
Change from Financial Plan 387,000 Therms 2,875 (3,065) (190)
1.5% 6.6% 6.9%
Water Utility
FY 2022 Financial Plan 4,508,000 CCF 48,817 (50,148) (1,332)
FY 2022 Projected 4,320,000 CCF 46,485 (49,333) (2,848)
Change from Financial Plan (188,000 CCF) (2,332) 815 (1,516)
(4.2%) (4.8%) (1.6%)
Wastewater Collection Utility
FY 2022 Financial Plan N/A 21,452 (21,733) (281)
FY 2022 Projected N/A 20,793 (22,247) (1,454)
Change from Financial Plan N/A (659) (514) (1,173)
(3.1%) 2.4%
Fiber Optic Utility
FY 2022 Financial Plan N/A 5,215 (3,304) 1,911
FY 2022 Projected N/A 4,515 (2,712) 1,803
Changes from Financial Plan N/A (700)
(13.4%)
(592)
(17.9%)
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Table 2: Operations Reserves, FY 2022 Projected ($,000)
Electric
Gas Water
Wastewater
Collection Fiber*
FY 2022 Beginning 29,903 11,981 20,773 6,578 33,343
FY 2022 Changes (18,372) (3,614) (9,483) (4,461) (325)
FY 2022 Ending (Projected) 11,531 8,367 11,290 2,117 33,018
Reserve Minimum 31,900 8,100 9,700 4,100 500
Reserve Maximum 63,700 16,200 19,400 10,100 1,100
* For Fiber Optics, the Reserve is the Rate Stabilization (not the Operations) Reserve
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Quarterly Update for Second Quarter of FY 2022
June 2022
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Residential Bill Comparisons
Table 3: Residential Electric Bill Comparison ($/month)
As of April 2022
Season Usage (KWh/mo) Palo Alto * PG&E Santa Clara Roseville
Winter
(Oct - May)
300 $45.17 $94.40 $39.22 $60.03
453 (Median) 75.11 142.54 59.95 76.37
650 115.82 219.54 86.65 104.80
1200 229.49 436.54 161.17 190.63
*Includes Hydro Rate Adjuster of $0.013/kwh, effective April 1, 2022
Table 4: Residential Natural Gas Bill Comparison ($/month)
As of April 2022
Season
Usage (therms
per month) Palo Alto
Menlo Park, Redwood City,
Mountain View, Los Altos, and
Santa Clara (PG&E Zone X)
Roseville
(PG&E Zone S)
Summer
(Apr - Oct)
15 $31.70 $29.49 $30.86
18 (Median) 35.86 36.74 38.11
30 60.75 65.71 67.08
45 93.91 101.92 103.29
Table 5: Residential Water Bill Comparison ($/month)
As of April 2022
Usage CCF/month Palo Alto
Menlo
Park
Redwood
City
Mountain
View Santa Clara Hayward
4 $46.89 $54.03 $54.04 $38.80 $26.76 $39.80
(Winter median) 7 70.28 77.71 76.09 60.07 46.83 61.34
(Annual median) 9 90.42 93.50 90.79 74.25 60.21 75.70
(Summer median) 14 140.77 136.35 138.94 109.70 93.66 119.80
25 251.54 241.76 267.39 230.19 167.25 216.82
Based on the FY 2013 BAWSCA survey, the fraction of SFPUC as the source of potable water supply was
100% for Palo Alto, 95% for Menlo Park, 100% for Redwood City, 87% for Mountain View, 10% for Santa
Clara and 100% for Hayward.
Table 6: Residential Wastewater Collection (Sewer) Bill Comparison ($/month)
As of April 2022
Palo Alto Menlo Park Redwood City Mountain View Los Altos Santa Clara Hayward
$43.32 $104.58 $89.28 $46.40 $40.83 $44.53 $37.17
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Quarterly Update for Second Quarter of FY 2022
June 2022
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Table 7: Median Residential Overall Bill Comparison ($/month)
As of April 2022
Utility and Usage Palo Alto
Menlo
Park
Redwood
City
Mountain
View
Santa
Clara Hayward
Electricity (453 kWh/mo) $75.11 $142.54 $142.54 $142.54 $59.95 $142.54
Gas (18 th/mo) 35.86 36.74 36.74 36.74 36.74 36.74
Water (9 CCF/mo) 90.42 93.50 90.79 74.25 60.21 75.70
Wastewater 43.32 104.58 89.28 46.40 44.53 37.17
TOTAL 244.71 377.36 359.35 299.93 201.43 292.15
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Table 8: FY 2022 Q2 Utilities Fund Reserve Report (‘000)
Beg inni ng C hanges t o Current IP r-ojected
Reserve Ba lance Reserves Reseive Balance
as of 7/0 1/21 Summ ary as of 12/31/2021
(FY 2022 ) (FY 2022)
Electr icity
SuppRy/D ist Operations $ 29 ,903 5 (18,372) $ 11 ,531
C IP :Reappm/C omm it 12,469 17,632 30 ,101
Hydro Stab iliiza ti on, 15,400 15,400
C IP Reserve 880 880
Rate Sta bilirzati on, --
P ubl ic Benefit 3,028 3,028
ESP 46 ,665 46 ,665
Low Carbon Fuel Standard 6,944 6,944
Cap & Tr ade 1,189 1 ,189
GASB 68 Pen s ion Rsrv (3 4,213) (34 ,21'3 )
GASB 75 OPE B Rsrv (13,233) (13,233)
A ll Othe rs 5,449 3,615 9,064
N et Capita l Investment 209,85 1' (408) 209 ,443
T otal $ 284,332 $ 2,467 $ 286,799
Gas
Ope rations Reserve 5 11 ,98 1 5 (3,614) $ 8,367
C IP Reserve 3,820 3,820
Rate Sta bil irzati on, 2,766 (1,510) 1 ,256
Cap & Tr ad e 4,542 4 ,542
C IP Reappm/C omm it. 7,11 2 1,502 8,6 14
GASB 68 Pen s ion Rs rv (14,792} (14 ,792)
GASB 75 OPIE B Rsrv (5,849), (5,849)
A ll Others 2,474 1,307 3,781
N et Capita l Investment 107,440 720 108,160
T otal 5 119,494 $ (1,595) 5 117,899
W ater
Ope rations Reserve 5 20 ,773 s (9,482) $ 11,29 1
CIP Reserve 10,707 10,707
Rate Sta bilirzati on, 9,069 9,069
C IP Reappm/C omm it. 10,147 11 ,801 2 1,948
GASB 68 Pe ns ion Rs rv (14,143) (14 ,143)
GASB 75 OPIE B Rsrv (4,054) (4 ,054)
A ll Others 3,391 1,144 4 ,535
N et Capita l Investment 105,676 963 106 ,639
T otal 5 14 1,566 $ 4,426 5 145 ,992
Fiber Op ti c
Rate Sta bilirzati on, $ 33 ,343 s (325) $ 33 ,0 18
C IP Reappm/Comm it. 2,055 (42) 2,0 13
GASB 68 Pen s ion Rs rv (2,238) (2,238)
GASB 75 OPIE B Rsrv (1) (1 )
A ll others 1,332 286 1,6 18
N et Capita l Investmen t 9,3 10 277 9,587
T otal $ 43 ,801 $ 196 $ 43 ,997
W as tew ater Coll ec tion
Operati ons Rese rv e $ 6,578 s (4,461) $ 2,1'.1'7
C IP Reserve 3,1 78 3,178
Rate Sta bilirzati on, 342 342
C IP Reappm/C omm it. 830 5,138 5,968
GASB 68 Pen s ion Rs rv (8 ,368} (8,368)
GASB 75 OPIE B Rsrv (2,236} (2,236)
A ll others 428 124 552
N et Capita l Investment 92,639 (1 ,153) 91 ,486
T otal $ 93 ,39 1 s (352) $ 93,039
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