Agenda packet — Lakeport City Council, October 21, 2025

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AGENDA

REGULAR MEETING OF THE LAKEPORT CITY COUNCIL
(ALSO MEETS AS THE CITY OF LAKEPORT MUNICIPAL SEWER DISTRICT, THE LAKEPORT INDUSTRIAL

DEVELOPMENT AUTHORITY, THE MUNICIPAL FINANCING AGENCY OF LAKEPORT, THE LAKEPORT GROUNDWATER SUSTAINABILITY AGENCY and THE SUCCESSOR AGENCY TO THE FORMER LAKEPORT

REDEVELOPMENT AGENCY)
Tuesday, October 21, 2025 6:00 p.m.

City Council Chambers, 225 Park Street, Lakeport, California 95453 See Teleconferencing Instructions Below
City Council Agenda of October 21, 2025 Page 2
AGENDA

REGULAR MEETING OF THE LAKEPORT CITY COUNCIL
(ALSO MEETS AS THE CITY OF LAKEPORT MUNICIPAL SEWER DISTRICT, THE

LAKEPORT INDUSTRIAL DEVELOPMENT AUTHORITY, THE MUNICIPAL FINANCING

AGENCY OF LAKEPORT, LAKEPORT GROUNDWATER SUSTAINABILITY AUTHORITY and THE SUCCESSOR AGENCY TO THE FORMER LAKEPORT REDEVELOPMENT AGENCY)*
Tuesday, October 21, 2025, 6:00 p.m.

City Council Chambers, 225 Park Street, Lakeport, California 95453 *All references to “City Council” include those other agencies which are listed above The City Council may discuss and/or take action on any or all of the items listed on the agenda irrespective of how the agenda items are described. The council may establish and make appointments to a Council committee (made up of two Councilmembers) with respect to any item appearing on this agenda.

I. CALL TO ORDER & ROLL CALL: 6:00 p.m.

II. PLEDGE OF ALLEGIANCE:

III. ACCEPTANCE OF AGENDA/ URGENCY
ITEMS:

Move to accept agenda as posted or move to add or delete items.

To add item, Council is required to make a majority decision that an urgency exists (as defined in the Brown Act) and a 2/3rds determination that the need to take action arose subsequent to the agenda being posted.

IV. CONSENT AGENDA: The following Consent Agenda items are expected to be routine and noncontroversial. They will be acted upon by the Council at one time without any discussion. Any Council Member may request that any item be removed from the Consent Agenda for discussion under the regular Agenda. Removed items will be considered following the Consent Calendar portion of this agenda.

A. Ordinances: Waive reading except by title, of any ordinances under consideration at this meeting for either introduction or passage per Government Code Section 36934.

B. Minutes: Approve the Minutes of the City Council Regular Meeting of September 16, 2025; the Special Meeting of September 30, 2025 and the Special Joint Meeting of September 30, 2025.

C. Warrants Approve the Warrant Register of September 22, 2025 D. Master Salary Schedule Update Approve a Resolution rescinding Resolution 2996 (2025) and revising the Master Pay Schedule in conformance with California Code of Regulations, Title 2, Section 570.5.

E. Notice of Completion: Pipeline
Project Adopt the resolution accepting construction of the 2024 Water & Sewer Main Replacement Project, by Ghilotti Construction Company and authorize the filing of the Notice of Completion.

F. Oil Spill Prevention Response Repeal and replace Resolution No. 3000 (2025), entering into a funding agreement with the California Department of Fish and Wildlife (CDFW), accepting grant funds, and authorizing the City Manager, or Public Works Director, to execute all documents for the Oil Spill Response Equipment Staging Grant, Lake County G. Application 2025-046 Approve application 2025-046, with staff recommendations, for Voter Parking.

V. PUBLIC PRESENTATIONS/REQUESTS:

A. Public Input: Any person may speak for 3 minutes about any subject within the authority of the City Council, provided that the subject is not already on tonight’s agenda. Per Government Code §54954.3(a), the City Council cannot take action or express a consensus of approval or disapproval on any public comments regarding matters which do not appear on the printed agenda.

City Council Agenda of October 21, 2025 Page 3
B. Presentation: Climate Action Plan Presentation by Lake County Community Development Department on the Climate Action Plan.

VI. PUBLIC HEARINGS:

A. Consideration of City of Lakeport
Joining Sonoma Clean Power 1. Adopt the resolution requesting that the Sonoma Clean Power Authority act as the Community Choice Aggregator for the City of Lakeport and authorize the implementation of Sonoma Clean Power’s Community Choice Aggregation Program within the City limits.

2. Introduce and waive the first reading of the ordinance authorizing the implementation of a Community Choice Aggregation Program within the City of Lakeport and approving the City’s participation in the Sonoma Clean Power Joint Powers Authority.

VII. COUNCIL BUSINESS:

A. Public Works Director

1. On-Call Consultant Contract Authorize City Manager to execute amendments to extend the terms of twelve on-call agreements by one year.

B. Finance Director

1. Budget Amendment Adopt the resolution to amend the annual budget for fiscal year 2025/26 to authorize the transfer and appropriation of unreserved fund balance.

2. Fourth Quarter Financial
Reports
Review and file the Fourth Quarter 2024/2025 Financial Update.

VIII. CITY COUNCIL COMMUNICATIONS:

A. Travel, Calendar, and
Miscellaneous Reports, if any:

IX. CLOSED SESSION: 1. CONFERENCE WITH LABOR NEGOTIATOR (Gov. Code § 54957.6)
City Negotiator: Mackenzie Anderson
Unrepresented Employee: City Manager
ADJOURNMENT:

Materials related to an item on this Agenda submitted to the Council after distribution of the agenda packet are available for public inspection in the City Clerk’s Office at 225 Park Street, Lakeport, California, during normal business hours. Such documents are also available on the City of Lakeport’s website, www.cityoflakeport.com, subject to staff’s ability to post the documents before the meeting.

The City of Lakeport, in complying with the Americans with Disabilities Act (ADA), requests individuals who require special accommodations to access, attend and/or participate in the City meeting due to disability, to please contact the City Clerk’s Office, (707) 263-5615, 72 hours prior to the scheduled meeting to ensure reasonable accommodations are provided.
_______________________________________
Kelly Buendia, City Clerk
If you cannot attend in person, and would like to speak on an agenda item, you can access the Zoom meeting remotely:

Join from a PC, Mac, iPad, iPhone or Android device:

Please click this URL to join. https://zoom.us/j/97368201787?pwd=a2NvVnN6MEFjQ2Exc2pTZkpIdU1sQT09 Passcode: 477973
Or join by phone:

Dial (for higher quality, dial a number based on your current location):

To give the City Clerk adequate time to print out your comments for consideration at the meeting, please submit your written comments prior to 3:30 p.m. on Tuesday, September 16, 2025.

Please indicate in the email Subject Line "FOR PUBLIC COMMENT" and list the item number you wish to comment on.

Comments that you want read to the Council will be subject to the three minute time limitation (approximately 350 words).

Written comments that are only to be provided to Council and not read at the meeting will be distributed to the Council prior to the meeting.

MINUTES

REGULAR MEETING OF THE LAKEPORT CITY COUNCIL
(ALSO MEETS AS THE CITY OF LAKEPORT MUNICIPAL SEWER DISTRICT, THE LAKEPORT INDUSTRIAL

DEVELOPMENT AUTHORITY, THE MUNICIPAL FINANCING AGENCY OF LAKEPORT, THE LAKEPORT GROUNDWATER SUSTAINABILITY AGENCY and THE SUCCESSOR AGENCY TO THE FORMER LAKEPORT

REDEVELOPMENT AGENCY)
Tuesday, September 16, 2025 6:00 p.m.

City Council Chambers, 225 Park Street, Lakeport, California 95453 See Teleconferencing Instructions Below
City Council Agenda of September 16, 2025 Page 2

MINUTES

REGULAR MEETING OF THE LAKEPORT CITY COUNCIL
(ALSO MEETS AS THE CITY OF LAKEPORT MUNICIPAL SEWER DISTRICT, THE

LAKEPORT INDUSTRIAL DEVELOPMENT AUTHORITY, THE MUNICIPAL FINANCING

AGENCY OF LAKEPORT, LAKEPORT GROUNDWATER SUSTAINABILITY AUTHORITY and THE SUCCESSOR AGENCY TO THE FORMER LAKEPORT REDEVELOPMENT AGENCY)*
Tuesday, September 16, 2025, 6:00 p.m.

I. CALL TO ORDER & ROLL CALL: Mayor Costa called the meeting to order at 6:01 p.m. with Council Members Disney, Mattina, Parlet and Price present.

A moment of silence was observed for Max Ruffcorn.

A moment of silence was observed for Charlie Kirk.

II. PLEDGE OF ALLEGIANCE: The Pledge of Allegiance was led by Lakeport Cub Scout Pack 142.

III. ACCEPTANCE OF AGENDA/ URGENCY
ITEMS:

A motion was made by Council Member Disney, seconded by Council Member Parlet, and unanimously carried by voice vote 5-0-0-0 to accept the agenda as posted.

A. Ordinances: Waive reading except by title, of any ordinances under consideration at this meeting for either introduction or passage per Government Code Section 36934.

B. Minutes: Approve the Minutes of the City Council regular meeting of September 2, 2025.

C. Memorandum of Understanding
with Lakeport Police Officers
Association:

Move to adopt a resolution approving a Memorandum of Understanding with the Lakeport Police Officers’ Association for the period of September 16, 2025, to June 30, 2028
D. Approve Modified Police Officer
Classification:

Move to approve the modified Police Officer I/ II/ III classification and job description.

A motion was made by Council Member Mattina, seconded by Council Member Parlet, and unanimously carried by voice vote 5-0-0-0 to approve the consent calendar as presented.

V. PUBLIC PRESENTATIONS/REQUESTS:

A. Public Input: Marie Schrader with Discover Lakeport CA reported on summer accomplishments with a growing Facebook reach.

Christina Reitz and Carl Porter on behalf of LMSA invited Council to participate as judges in the Chili Cookoff on October 11, 2025.

Wilda Shock shared that Mendocino College is holding a facilities planning meeting to be held at the Lake Center at noon on October 2, 2025, and they would like to hear from public.

City Council Agenda of September 16, 2025 Page 3
Phil Smoley invited the public to a vigil for Charlie Kirk at Library Park on September 17 at 7:30 and invited public to attend.

B. Presentation: Presentation of Blue Zones Designation to City of Lakeport by Blue Zones Lake County Administrative Services Director Buendia gave an overview of Wellness Committee activities and accomplishments. Kelly Yandell and Jamy Gill of Blue Zones Lake County presented the City of Lakeport with the Blue Zones Designation and ribbon cutting.

VI. PUBLIC HEARINGS:

VII. COUNCIL BUSINESS:

A. Public Works Director

1. Lake County MultiJurisdictional Hazard
Mitigation Plan:

The staff report was presented by Public Works Director Ladd.

A motion was made by Council Member Disney, seconded by Council Member Parlet, and unanimously carried by voice vote 5-0-0-0 to adopt the proposed resolution approving the Lake County Multi-Jurisdictional Hazard Mitigation Plan (MJHMP) and direct staff to prepare a future General Plan amendment to incorporate relevant data, goals, and policies into the Safety Element of the City of Lakeport General Plan.

VIII. CITY COUNCIL COMMUNICATIONS:

City Council Agenda of September 16, 2025 Page 4
A. Travel, Calendar, and
Miscellaneous Reports, if any:

City Manager Ingram announced that a Special joint meeting Sept. 30, 5 p.m. with City Council, Board of Supervisors, and Clearlake City Council will be held to review Sonoma Clean Power proposal. He reminded the City Council that the Oct. 7 City Council meeting is cancelled and that pending event applications may be handled Sept. 30 or in a short special meeting before National Night Out.

Assistant City Attorney Anderson will be attending League of California Cities conference in Long Beach with the firm mixer to be held Oct. 9 at 6 p.m. at Hyatt Regency. She clarified that the fee study from the 9/2/25 meeting is not subject to Prop 218 and will follow Mitigation Fee Act with required notices.

Chief Stoebe announced that Officer Juan Villa completed Field Training. He invited the public and City Council to National Night Out on Oct. 7.

Administrative Services Director Buendia gave no report.

Public Works Director Ladd reminded the Council about the Coastal Clean-Up Day Sept. 21 at Library Park with Clear Lake Environmental Impact Club participation. The Club may also be assisting with sidewalk inventory project.

Council Member Mattina stated that the LAFCO meeting is scheduled for Sept. 20 in Clearlake.

Mayor Pro Tem Disney stated that the LCRA is focusing on long-term projects (pool, rec center) and short-term events. He announced the upcoming Trucks on Track event (Sept. 20) and the Konocti Climb race (Nov. 9).

Council Member Price shared some calendar items: LMSA calendar: Harvest Festival (Oct. 11), basketball tournament at Xabatin Park, Pomo Room museum event (Sept. 20); Walk to School event Sept. 20; and Invited participation in Coastal Clean-Up Day.

Council Member Parlet reported low Lake Transit subsidies. He also stated that the NREN discussing change from percentage-based to flat energy fee for business contributions.

Mayor Costa praised success of LEDAC Mixer. She further shared that she met with Congressman Thompson to discuss projects and funding. She stated that the Risk Reduction Authority continued discussions on home hardening benefits.

IX. CLOSED SESSION: Mayor Costa adjourned to Closed Session at 7:18 p.m. to consider:

1. Conference with Legal Counsel; Existing Litigation (Gov. Code § 54956.9(d)(1)). The City Council finds, based on advice from legal counsel, that discussion in open session will prejudice the position of the local agency in the litigation.

A. In re: National Prescription Opiate Litigation, Case No. 1:17-md-02804- DAP, pending in the U.S. District Court for the Northern District of Ohio.

Plaintiff: City of Lakeport. Defendants: Alvogen, Amneal, Apotex, Hikma, Indivior, Mylan, Sun Pharma, Zydus, and Sandoz
Mayor Costa adjourned the Closed Session at 7:37 p.m. without reportable action.

City Council Agenda of September 16, 2025 Page 5
ADJOURNMENT: Mayor Costa adjourned the meeting at 7:37 p.m.

The City of Lakeport, in complying with the Americans with Disabilities Act (ADA), requests individuals who require special accommodations to access, attend and/or participate in the City meeting due to disability, to please contact the City Clerk’s Office, (707) 263-5615, 72 hours prior to the scheduled meeting to ensure reasonable accommodations are provided.
_______________________________________
Kim Costa, Mayor
Attest:
_______________________________________
Kelly Buendia, City Clerk

1. Call to Order and Roll Call: Mayor Costa called the meeting to order at 4:01 p.m. with Council Members Disney, Mattina, and Parlet present.

Councilmember Price was absent.

2. Application 2025-036
Revision:

The item was presented by City Clerk Buendia.

A motion was made by Council Member Disney, seconded
by Council Member Mattina, and unanimously carried by
voice vote 4-0-1-0 to approve revised application 2025-036, with staff recommendations, for the LMSA Harvest Festival event.

3. Application 2025-043: The item was presented by City Clerk Buendia.

A motion was made by Council Member Mattina, seconded
by Council Member Disney, and unanimously carried by
voice vote 4-0-1-0 to approve application 2025-043, with staff recommendations, for the All Tribes Benefit for KPFZ event.

4. Application 2025-044: The item was presented by City Clerk Buendia.

A motion was made by Council Member Mattina, seconded
by Council Member Disney, and unanimously carried by
voice vote 4-0-1-0 to approve application 2025-044,
conditioned upon staff recommendations, for the CLHS &
Lakeport Elementary Halloween Parade.

MINUTES

SPECIAL MEETING

OF THE LAKEPORT CITY COUNCIL
Tuesday, September 30, at 4:00 p.m.

City Council Chambers, 225 Park Street, Lakeport, California 95453

5. Application 2025-045: The item was presented by City Clerk Buendia.

A motion was made by Council Member Disney, seconded
by Council Member Mattina, and unanimously carried by
voice vote 4-0-1-0 to approve application 2025-045, with staff recommendations, for the Trick or Treat Main Street event.

Adjournment: Mayor Costa adjourned the meeting at 4:09 p.m. ____________________________________
Kim Costa, Mayor
Attest:
__________________________________
Kelly Buendia, City Clerk

MINUTES
Special Meeting of the Lake County Board of Supervisors Joint Workshop of County of Lake and Cities of Clearlake and Lakeport on the Option of Public Power Generation in Lake County with Sonoma Clean Power
Tuesday, September 30, 2025 at 5:00 P.M.

County of Lake Courthouse - Board Chambers
255 N. Forbes Street, Lakeport, CA 95453
To listen and/or participate via Zoom Webinar:
https://lakecounty.zoom.us/j/86533544962?pwd=eFU3SWhhVlR4OGtqK1hPLzI0N2F0dz09 Webinar ID: 865 3354 4962
Passcode: 726865
One tap mobile: +16694449171, 86533544962#,*726865#
Collaborating entities: County of Lake, City of Clearlake, and City of Lakeport

1. The Meeting was called to order at 5:00 p.m.by Chair Crandell.

2. The Pledge of Allegiance was led by Lakeport Mayor Costa.

3. Welcome and Introductions:
- In attendance for Lake County: Supervisors Crandell, Owen, Pyska, Rasmussen, Sabatier. - In attendance for City of Clearlake: Council members Downey, Wilson, Cremer, and Hooten. - In attendance for City of Lakeport: Council members Costa, Disney, Mattina, and Parlet.

4. Presentation and Discussion by Sonoma Clean Power
Mathew Rothstein, Chief Deputy County Administrative Officer, presented a staff report.

Representatives from Sonoma Clean Power delivered a presentation. Representatives from Sonoma Clean Power included:
- Geof Syphers, Chief Executive Officer;
- John Haschak, Mendocino County Supervisor/SCP Board Member; - Erica Torgerson, Managing Director of Customer Service; and, - Ryan Tracey, Director of Planning & Analytics; and,
- Josh Nelson, Special Counsel.
- Neal Reardon, Director of Regulatory Affairs;
- Miles Horton, Legislative Policy & Community Engagement Manager;( in the room?) Members of the three boards directed questions to the presenters.

5. Public Q & A
- First Speaker (name ineligible) – Opposed
- Lisa Marie Benvanitas – Opposed
- Third Speaker (name not provided) – Need more details, particularly on GeoZone. - Fourth Speaker (name not provided) – Need more details and attention to land use aspects. - Nicole Flora – Asked a question about opt out/participation rates. - Denise Rushing – In Support
- Stirling Wellman - Opposed
Additional discussion and commentary were offered by the three boards.

6. Adjournment – Chair Crandell adjourned the meeting at 7:20 p.m. 225 PARK STREET • LAKEPORT, CALIFORNIA 95453 • TELEPHONE (707) 263-5615 • FAX (707) 263-8584

CITY OF LAKEPORT
Over 125 years of community
pride, progress and service
9/22/2025
I hereby certify that the attached list of warrants has been audited, extensions are proper, purchase orders have been issued, and department heads have been given the opportunity to review and sign claim forms. ______________________________
Danielle Dizon
Finance Director
9/22/2025 3:44:50 PM Page 1 of 13
Bank Transaction Report
Lakeport Transaction Detail
Issued Date Range: 07/22/2025 - 09/19/2025
Cleared Date Range: -
Cleared
Date Number Description Module Status Type Amount
Issued
Date
Bank Account: 15-0352000798 - POOLED CASH BANK
07/24/2025 60842 COUNTY OF LAKE Accounts Payable Outstanding Check -50.00 07/24/2025 APA008019 4LEAF, INC. Accounts Payable Outstanding AP Automation -8,345.00 07/24/2025 APA008020 AGD GENERAL ENGINEERING Accounts Payable Outstanding AP Automation -1,933.55 07/24/2025 APA008021 APEX TECHNOLOGY MGMT, INC. Accounts Payable Outstanding AP Automation -2,260.64 07/24/2025 APA008022 APPLIED BUSINESS SOFTWARE, INC. Accounts Payable Outstanding AP Automation -4,932.87 07/24/2025 APA008023 AT&T Accounts Payable Outstanding AP Automation -112.83 07/24/2025 APA008024 AT&T Accounts Payable Outstanding AP Automation -251.45 07/24/2025 APA008025 AT&T Accounts Payable Outstanding AP Automation -251.45 07/24/2025 APA008026 AT&T Accounts Payable Outstanding AP Automation -31.54 07/24/2025 APA008027 AT&T MOBILITY Accounts Payable Outstanding AP Automation -40.24 07/24/2025 APA008028 BANNER BANK Accounts Payable Outstanding AP Automation -191,246.75 07/24/2025 APA008029 BRAY SALES, INC Accounts Payable Outstanding AP Automation -1,424.54 07/24/2025 APA008030 COPWARE, INC. Accounts Payable Outstanding AP Automation -705.00 07/24/2025 APA008031 COUNTY OF LAKE-SPECIAL DIST Accounts Payable Outstanding AP Automation -68,359.85 07/24/2025 APA008032 CPR1 Accounts Payable Outstanding AP Automation -3,381.35 07/24/2025 APA008033 DAVIS TIRE & AUTO REPAIR Accounts Payable Outstanding AP Automation -885.56 07/24/2025 APA008034 DEPT OF JUSTICE Accounts Payable Outstanding AP Automation -482.00 07/24/2025 APA008035 DUDEK Accounts Payable Outstanding AP Automation -6,642.09 07/24/2025 APA008036 FED EX Accounts Payable Outstanding AP Automation -21.19 07/24/2025 APA008037 FERRELLGAS Accounts Payable Outstanding AP Automation -71.47 07/24/2025 APA008038 GHILOTTI CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -813,801.75 07/24/2025 APA008039 GRAINGER Accounts Payable Outstanding AP Automation -1,547.28 07/24/2025 APA008040 GRANITE CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -3,854.91 07/24/2025 APA008041 IT'S ABOUT TIME, INC Accounts Payable Outstanding AP Automation -397.05 07/24/2025 APA008042 L. N. CURTIS & SONS Accounts Payable Outstanding AP Automation -379.85 07/24/2025 APA008043 LAKE COUNTY RECORD BEE Accounts Payable Outstanding AP Automation -545.52 07/24/2025 APA008044 MEDIACOM Accounts Payable Outstanding AP Automation -316.92 07/24/2025 APA008045 MENDO MILL & LUMBER CO. Accounts Payable Outstanding AP Automation -2,197.87 07/24/2025 APA008046 PACE ENGINEERING, INC. Accounts Payable Outstanding AP Automation -24,675.50 07/24/2025 APA008047 PACE SUPPLY #03391-00 Accounts Payable Outstanding AP Automation -2,887.84 07/24/2025 APA008048 PAUL R. CURREN Accounts Payable Outstanding AP Automation -2,981.25 07/24/2025 APA008049 PG&E Accounts Payable Outstanding AP Automation -11.07 07/24/2025 APA008050 PITNEY BOWES BANK INC PURCHASE POWER Accounts Payable Outstanding AP Automation -264.99 07/24/2025 APA008051 PRECISION WIRELESS SERVICE Accounts Payable Outstanding AP Automation -1,925.00 07/24/2025 APA008052 RAINBOW AGRICULTURAL SERVICES Accounts Payable Outstanding AP Automation -1,008.23 07/24/2025 APA008053 RB PEST CONTROL Accounts Payable Outstanding AP Automation -140.00 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 2 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
07/24/2025 APA008054 REMIF Accounts Payable Outstanding AP Automation -109,822.40 07/24/2025 APA008055 RICH-TED TRUCKING, INC. Accounts Payable Outstanding AP Automation -680.00 07/24/2025 APA008056 RICOH USA, INC. Accounts Payable Outstanding AP Automation -11.50 07/24/2025 APA008057 ROBERT NISHIYAMA Accounts Payable Outstanding AP Automation -641.70 07/24/2025 APA008058 SHRED-IT USA LLC Accounts Payable Outstanding AP Automation -218.10 07/24/2025 APA008059 SONOMA RSA, INC Accounts Payable Outstanding AP Automation -1,280.00 07/24/2025 APA008060 SOUTHERN CALIFORNIA RADAR LASER CERTIFICATION LAB Accounts Payable Outstanding AP Automation -220.00 07/24/2025 APA008061 SUTTER LAKESIDE HOSPITAL Accounts Payable Outstanding AP Automation -25.00 07/24/2025 APA008062 SWAN ANALYTICAL INSTRUMENTS Accounts Payable Outstanding AP Automation -868.65 07/24/2025 APA008063 THE SHOE BOX Accounts Payable Outstanding AP Automation -200.00 07/24/2025 APA008064 US BANK NATIONAL ASSOCIATION Accounts Payable Outstanding AP Automation -235,448.47 07/24/2025 APA008065 USA BLUE BOOK Accounts Payable Outstanding AP Automation -2,117.67 07/24/2025 APA008066 VELOCITY EHS, INC. Accounts Payable Outstanding AP Automation -953.88 07/24/2025 APA008067 VESTIS Accounts Payable Outstanding AP Automation -39.69 07/24/2025 APA008068 VIALYTICS Accounts Payable Outstanding AP Automation -7,205.00 07/24/2025 APA008069 WESTGATE PETROLEUM CO., INC. Accounts Payable Outstanding AP Automation -2,483.88 07/24/2025 APA008070 YOLO COUNTY FLOOD CONTROL Accounts Payable Outstanding AP Automation -2,998.78 07/25/2025 60830 AFLAC Accounts Payable Outstanding Check -667.98 07/25/2025 60831 AIR MED CARE NETWORK Accounts Payable Outstanding Check -3,650.00 07/25/2025 60832 CA STATE DISBURSEMENT UNIT Accounts Payable Outstanding Check -398.07 07/25/2025 60833 FRANCHISE TAX BOARD Accounts Payable Outstanding Check -50.00 07/25/2025 60834 LAKEPORT EMPLOYEE'S ASSOC Accounts Payable Outstanding Check -360.00 07/25/2025 60835 LEGALSHIELD Accounts Payable Outstanding Check -357.25 07/25/2025 60836 LPOA Accounts Payable Outstanding Check -670.00 07/25/2025 60837 NATIONWIDE RETIREMENT SOLUTION Accounts Payable Outstanding Check -975.00 07/25/2025 60838 VALIC - C/O JP MORGAN CHASE Accounts Payable Outstanding Check -2,313.92 07/25/2025 DFT0003956 CALPERS Accounts Payable Outstanding Bank Draft -3,992.01 07/25/2025 DFT0003957 CALPERS Accounts Payable Outstanding Bank Draft -4,061.70 07/25/2025 DFT0003958 CALPERS Accounts Payable Outstanding Bank Draft -5,849.22 07/25/2025 DFT0003959 CALPERS Accounts Payable Outstanding Bank Draft -6,007.73 07/25/2025 DFT0003960 CALPERS Accounts Payable Outstanding Bank Draft -3,836.07 07/25/2025 DFT0003961 CALPERS Accounts Payable Outstanding Bank Draft -6,799.43 07/25/2025 DFT0003962 CALPERS Accounts Payable Outstanding Bank Draft -514.79 07/25/2025 DFT0003963 CALPERS Accounts Payable Outstanding Bank Draft -1,395.66 07/25/2025 DFT0003964 CALPERS Accounts Payable Outstanding Bank Draft -50.22 07/25/2025 DFT0003965 CALPERS Accounts Payable Outstanding Bank Draft -6.91 07/25/2025 DFT0003966 IRS Accounts Payable Outstanding Bank Draft -4,696.62 07/25/2025 DFT0003967 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -5,563.53 07/25/2025 DFT0003968 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -1,934.03 07/25/2025 DFT0003969 IRS Accounts Payable Outstanding Bank Draft -14,164.21 07/25/2025 DFT0003970 IRS Accounts Payable Outstanding Bank Draft -322.40 07/30/2025 60843 BETHANY MOSS Accounts Payable Outstanding Check -1,658.48 07/30/2025 60844 CA BLDG STANDARDS COMMISSION Accounts Payable Outstanding Check -73.30 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 3 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
07/30/2025 60845 DEPT OF CONSERVATION Accounts Payable Outstanding Check -386.58 07/30/2025 60846 DIVISION OF STATE ARCHITECT Accounts Payable Outstanding Check -226.80 07/30/2025 60847 SEBIS DIRECT, INC - POSTAGE Accounts Payable Outstanding Check -3,400.00 07/31/2025 APA008071 AmWINS GROUP BENEFITS, INC. Accounts Payable Outstanding AP Automation -25,889.15 07/31/2025 APA008072 AT&T Accounts Payable Outstanding AP Automation -214.00 07/31/2025 APA008073 AT&T CALNET3 Accounts Payable Outstanding AP Automation -142.88 07/31/2025 APA008074 BRAY INTERNATIONAL, INC Accounts Payable Outstanding AP Automation -405.39 07/31/2025 APA008075 BRELJE & RACE CONSULTING ENGINEERS Accounts Payable Outstanding AP Automation -11,990.00 07/31/2025 APA008076 CALIF INTERGOVERNMENTAL RISK AUTHORITY Accounts Payable Outstanding AP Automation -936,441.41 07/31/2025 APA008077 CALIF POLICE CHIEFS ASSN. Accounts Payable Outstanding AP Automation -450.00 07/31/2025 APA008078 CONDOR EARTH TECHNOLOGIES INC. Accounts Payable Outstanding AP Automation -11,236.63 07/31/2025 APA008079 DOKKEN ENGINEERING Accounts Payable Outstanding AP Automation -6,191.77 07/31/2025 APA008080 GRANITE CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -1,052,000.49 07/31/2025 APA008081 GROW WEST Accounts Payable Outstanding AP Automation -839.41 07/31/2025 APA008082 HANKIN SPECIALTY ELEVATORS, INC. Accounts Payable Outstanding AP Automation -13,661.92 07/31/2025 APA008083 INSURANCE AND BENEFITS TRUST OF PORAC Accounts Payable Outstanding AP Automation -346.50 07/31/2025 APA008084 MANAGEMENT CONNECTIONS Accounts Payable Outstanding AP Automation -414.24 07/31/2025 APA008085 MEDIACOM Accounts Payable Outstanding AP Automation -59.36 07/31/2025 APA008086 MIKSIS SERVICES, INC. Accounts Payable Outstanding AP Automation -7,000.00 07/31/2025 APA008087 NAPA AUTO - LAKE PARTS Accounts Payable Outstanding AP Automation -794.33 07/31/2025 APA008088 NTU TECHNOLOGIES INC Accounts Payable Outstanding AP Automation -5,251.00 07/31/2025 APA008089 POLESTAR COMPUTERS Accounts Payable Outstanding AP Automation -7,994.13 07/31/2025 APA008090 R.S. HUGHES Accounts Payable Outstanding AP Automation -78.82 07/31/2025 APA008091 R3 CONSULTING GROUP, INC. Accounts Payable Outstanding AP Automation -1,925.00 07/31/2025 APA008092 RB PEST CONTROL Accounts Payable Outstanding AP Automation -180.00 07/31/2025 APA008093 REMIF Accounts Payable Outstanding AP Automation -183.00 07/31/2025 APA008094 RICOH USA, INC. Accounts Payable Outstanding AP Automation -491.23 07/31/2025 APA008095 SHN CONSULTING ENGINEERS & GEO Accounts Payable Outstanding AP Automation -391.25 07/31/2025 APA008096 STAPLES BUSINESS ADVANTAGE Accounts Payable Outstanding AP Automation -1,357.39 07/31/2025 APA008097 THATCHER COMPANY OF CA., INC. Accounts Payable Outstanding AP Automation -8,897.51 07/31/2025 APA008098 THE BRIEFING ROOM LLC Accounts Payable Outstanding AP Automation -461.08 07/31/2025 APA008099 THE SHOE BOX Accounts Payable Outstanding AP Automation -579.44 07/31/2025 APA008100 TOTAL COMPENSATION SYSTEMS, INC. Accounts Payable Outstanding AP Automation -1,215.00 07/31/2025 APA008101 UNDERGROUND SERVICE ALERT Accounts Payable Outstanding AP Automation -300.00 07/31/2025 APA008102 VESTIS Accounts Payable Outstanding AP Automation -39.69 07/31/2025 APA008103 VISIT LAKE COUNTY CALIFORNIA Accounts Payable Outstanding AP Automation -127.20 07/31/2025 APA008104 WESTGATE PETROLEUM CO., INC. Accounts Payable Outstanding AP Automation -87.25 07/31/2025 APA008105 WILDA SHOCK Accounts Payable Outstanding AP Automation -1,500.00 07/31/2025 APA008106 WMH CORPORATION Accounts Payable Outstanding AP Automation -45,818.69 08/04/2025 APA007925 AIR MED CARE NETWORK Reversal Accounts Payable Outstanding AP Automation Reversal 3,650.00 08/08/2025 60848 AFLAC Accounts Payable Outstanding Check -667.98 08/08/2025 60849 CA STATE DISBURSEMENT UNIT Accounts Payable Outstanding Check -398.07 08/08/2025 60850 FRANCHISE TAX BOARD Accounts Payable Outstanding Check -50.00 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 4 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
08/08/2025 60851 LAKEPORT EMPLOYEE'S ASSOC Accounts Payable Outstanding Check -360.00 08/08/2025 60852 LPOA Accounts Payable Outstanding Check -670.00 08/08/2025 60853 NATIONWIDE RETIREMENT SOLUTION Accounts Payable Outstanding Check -1,075.00 08/08/2025 60854 VALIC - C/O JP MORGAN CHASE Accounts Payable Outstanding Check -2,313.92 08/08/2025 DFT0003971 CALPERS Accounts Payable Outstanding Bank Draft -4,055.90 08/08/2025 DFT0003972 CALPERS Accounts Payable Outstanding Bank Draft -4,126.69 08/08/2025 DFT0003973 CALPERS Accounts Payable Outstanding Bank Draft -5,863.84 08/08/2025 DFT0003974 CALPERS Accounts Payable Outstanding Bank Draft -6,022.75 08/08/2025 DFT0003975 CALPERS Accounts Payable Outstanding Bank Draft -3,847.03 08/08/2025 DFT0003976 CALPERS Accounts Payable Outstanding Bank Draft -6,818.85 08/08/2025 DFT0003977 CALPERS Accounts Payable Outstanding Bank Draft -514.79 08/08/2025 DFT0003978 CALPERS Accounts Payable Outstanding Bank Draft -1,395.66 08/08/2025 DFT0003979 CALPERS Accounts Payable Outstanding Bank Draft -50.22 08/08/2025 DFT0003980 CALPERS Accounts Payable Outstanding Bank Draft -6.91 08/08/2025 DFT0003981 IRS Accounts Payable Outstanding Bank Draft -4,599.92 08/08/2025 DFT0003982 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -5,331.26 08/08/2025 DFT0003983 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -1,901.21 08/08/2025 DFT0003984 IRS Accounts Payable Outstanding Bank Draft -13,672.52 08/08/2025 DFT0003985 IRS Accounts Payable Outstanding Bank Draft -204.60 08/11/2025 60855 DALE STOEBE Accounts Payable Outstanding Check -302.22 08/11/2025 60856 DYLAN TEVERBAUGH Accounts Payable Outstanding Check -194.12 08/11/2025 APA008107 ALPHA ANALYTICAL LABORATORIES Accounts Payable Outstanding AP Automation -341.00 08/11/2025 APA008108 AMAZON CAPITAL SERVICES, INC. Accounts Payable Outstanding AP Automation -247.51 08/11/2025 APA008109 AMERICAN RIVER COLLEGE Accounts Payable Outstanding AP Automation -92.00 08/11/2025 APA008110 AmWINS GROUP BENEFITS, INC. Accounts Payable Outstanding AP Automation -25,889.15 08/11/2025 APA008111 AT&T CALNET3 Accounts Payable Outstanding AP Automation -251.09 08/11/2025 APA008112 AT&T CALNET3 Accounts Payable Outstanding AP Automation -94.74 08/11/2025 APA008113 AT&T CALNET3 Accounts Payable Outstanding AP Automation -383.74 08/11/2025 APA008114 AT&T CALNET3 Accounts Payable Outstanding AP Automation -295.13 08/11/2025 APA008115 COUNTY OF LAKE-ANIMAL CONTROL Accounts Payable Outstanding AP Automation -5,226.57 08/11/2025 APA008116 EAST BAY TIRE / R&G TIRE CENTR Accounts Payable Outstanding AP Automation -472.46 08/11/2025 APA008117 EUREKA OXYGEN COMPANY Accounts Payable Outstanding AP Automation -400.51 08/11/2025 APA008118 FED EX Accounts Payable Outstanding AP Automation -9.84 08/11/2025 APA008119 FERRELLGAS Accounts Payable Outstanding AP Automation -70.41 08/11/2025 APA008120 IT'S ABOUT TIME, INC Accounts Payable Outstanding AP Automation -43.50 08/11/2025 APA008121 KELSEYVILLE LUMBER Accounts Payable Outstanding AP Automation -147.99 08/11/2025 APA008122 LAKE COUNTY ELECTRIC SUPPLY Accounts Payable Outstanding AP Automation -46.93 08/11/2025 APA008123 O'REILLY AUTO PARTS Accounts Payable Outstanding AP Automation -329.15 08/11/2025 APA008124 PACE SUPPLY #03391-00 Accounts Payable Outstanding AP Automation -2,896.08 08/11/2025 APA008125 PAUL R. CURREN Accounts Payable Outstanding AP Automation -4,240.00 08/11/2025 APA008126 PG&E Accounts Payable Outstanding AP Automation -1,348.54 08/11/2025 APA008127 PG&E Accounts Payable Outstanding AP Automation -1,937.81 08/11/2025 APA008128 PG&E Accounts Payable Outstanding AP Automation -7,091.95 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 5 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
08/11/2025 APA008129 PG&E Accounts Payable Outstanding AP Automation -935.20 08/11/2025 APA008130 PG&E Accounts Payable Outstanding AP Automation -325.13 08/11/2025 APA008131 PG&E Accounts Payable Outstanding AP Automation -1,797.76 08/11/2025 APA008132 PG&E Accounts Payable Outstanding AP Automation -112.19 08/11/2025 APA008133 PG&E Accounts Payable Outstanding AP Automation -10,055.68 08/11/2025 APA008134 PG&E Accounts Payable Outstanding AP Automation -383.19 08/11/2025 APA008135 PG&E Accounts Payable Outstanding AP Automation -357.47 08/11/2025 APA008136 R.S. HUGHES Accounts Payable Outstanding AP Automation -158.23 08/11/2025 APA008137 R3 CONSULTING GROUP, INC. Accounts Payable Outstanding AP Automation -615.00 08/11/2025 APA008138 RAINBOW AGRICULTURAL SERVICES Accounts Payable Outstanding AP Automation -21.41 08/11/2025 APA008139 RICOH USA, INC. Accounts Payable Outstanding AP Automation -240.07 08/11/2025 APA008140 SHN CONSULTING ENGINEERS & GEO Accounts Payable Outstanding AP Automation -3,964.00 08/11/2025 APA008141 STAPLES BUSINESS ADVANTAGE Accounts Payable Outstanding AP Automation -608.75 08/11/2025 APA008142 THE SHOE BOX Accounts Payable Outstanding AP Automation -600.00 08/11/2025 APA008143 THE UPS STORE #5161 Accounts Payable Outstanding AP Automation -14.79 08/11/2025 APA008144 UKIAH PAPER SUPPLY, INC. Accounts Payable Outstanding AP Automation -6,403.91 08/11/2025 APA008145 USA BLUE BOOK Accounts Payable Outstanding AP Automation -2,807.57 08/14/2025 60857 KATIE MORFIN Accounts Payable Outstanding Check -441.00 08/14/2025 60858 LAKEPORT DISPOSAL, INC. Accounts Payable Outstanding Check -109,918.26 08/14/2025 60859 SWRCB Accounts Payable Outstanding Check -228.00 08/22/2025 60860 AFLAC Accounts Payable Outstanding Check -667.98 08/22/2025 60861 CA STATE DISBURSEMENT UNIT Accounts Payable Outstanding Check -398.07 08/22/2025 60862 FRANCHISE TAX BOARD Accounts Payable Outstanding Check -50.00 08/22/2025 60863 LAKEPORT EMPLOYEE'S ASSOC Accounts Payable Outstanding Check -360.00 08/22/2025 60864 LEGALSHIELD Accounts Payable Outstanding Check -357.25 08/22/2025 60865 LPOA Accounts Payable Outstanding Check -670.00 08/22/2025 60866 NATIONWIDE RETIREMENT SOLUTION Accounts Payable Outstanding Check -1,075.00 08/22/2025 60867 VALIC - C/O JP MORGAN CHASE Accounts Payable Outstanding Check -2,313.92 08/22/2025 APA008146 AMAZON CAPITAL SERVICES, INC. Accounts Payable Outstanding AP Automation -5,084.80 08/22/2025 APA008147 AT&T Accounts Payable Outstanding AP Automation -3,351.44 08/22/2025 APA008148 CALIF POLICE CHIEFS ASSN. Accounts Payable Outstanding AP Automation -170.00 08/22/2025 APA008149 CLEARLAKE REDI-MIX INC. Accounts Payable Outstanding AP Automation -2,518.65 08/22/2025 APA008150 COLANTUONO, HIGHSMITH & WHATLEY, PC Accounts Payable Outstanding AP Automation -11,718.65 08/22/2025 APA008151 COMMUNITY DEVELOPMENT SERVICES Accounts Payable Outstanding AP Automation -1,275.00 08/22/2025 APA008152 DEEP VALLEY SECURITY Accounts Payable Outstanding AP Automation -620.30 08/22/2025 APA008153 EAST BAY TIRE / R&G TIRE CENTR Accounts Payable Outstanding AP Automation -275.38 08/22/2025 APA008154 EBA ENGINEERING Accounts Payable Outstanding AP Automation -3,322.00 08/22/2025 APA008155 GHILOTTI CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -226,375.08 08/22/2025 APA008156 GRANITE CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -5,628.02 08/22/2025 APA008157 IRONEDGE GROUP Accounts Payable Outstanding AP Automation -225.00 08/22/2025 APA008158 JONES TOWING Accounts Payable Outstanding AP Automation -150.00 08/22/2025 APA008159 LAKE COUNTY BROADBAND SOLUTIONS Accounts Payable Outstanding AP Automation -99.00 08/22/2025 APA008160 LEXIS NEXIS RISK SOLUTIONS Accounts Payable Outstanding AP Automation -200.00 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 6 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
08/22/2025 APA008161 MANAGEMENT CONNECTIONS Accounts Payable Outstanding AP Automation -2,803.50 08/22/2025 APA008162 MANAGEMENT CONNECTIONS (Cloverdale) Accounts Payable Outstanding AP Automation -75.00 08/22/2025 APA008163 MC ENGINEERING, INC Accounts Payable Outstanding AP Automation -1,107.50 08/22/2025 APA008164 MENDO MILL & LUMBER CO. Accounts Payable Outstanding AP Automation -3,006.48 08/22/2025 APA008165 MUNISERVICES Accounts Payable Outstanding AP Automation -636.68 08/22/2025 APA008166 NUSO Accounts Payable Outstanding AP Automation -278.19 08/22/2025 APA008167 ONLINE INFORMATION SERVICES Accounts Payable Outstanding AP Automation -44.64 08/22/2025 APA008168 OPENGOV, INC Accounts Payable Outstanding AP Automation -96,961.73 08/22/2025 APA008169 O'REILLY AUTO PARTS Accounts Payable Outstanding AP Automation -36.40 08/22/2025 APA008170 PACE SUPPLY #03391-00 Accounts Payable Outstanding AP Automation -3,653.72 08/22/2025 APA008171 PAUL R. CURREN Accounts Payable Outstanding AP Automation -795.00 08/22/2025 APA008172 PEOPLE SERVICES, INC. Accounts Payable Outstanding AP Automation -200.00 08/22/2025 APA008173 PG&E Accounts Payable Outstanding AP Automation -40,210.57 08/22/2025 APA008174 PIAZZA CONSTRUCTION Accounts Payable Outstanding AP Automation -3,907.20 08/22/2025 APA008175 PITNEY BOWES INC Accounts Payable Outstanding AP Automation -502.25 08/22/2025 APA008176 PRECISION WIRELESS SERVICE Accounts Payable Outstanding AP Automation -1,750.00 08/22/2025 APA008177 R.S. HUGHES Accounts Payable Outstanding AP Automation -119.45 08/22/2025 APA008178 RICOH - WELLS FARGO VENDOR FIN SVCS, LLC Accounts Payable Outstanding AP Automation -315.91 08/22/2025 APA008179 RICOH USA, INC. Accounts Payable Outstanding AP Automation -529.84 08/22/2025 APA008180 SEBIS DIRECT, INC. - PRINTING Accounts Payable Outstanding AP Automation -519.15 08/22/2025 APA008181 SUN RIDGE SYSTEMS, INC. Accounts Payable Outstanding AP Automation -8,445.00 08/22/2025 APA008182 THE UPS STORE #5161 Accounts Payable Outstanding AP Automation -14.35 08/22/2025 APA008183 TRI-CITIES ANSWERING SERVICE Accounts Payable Outstanding AP Automation -133.22 08/22/2025 APA008184 U.S. BANK CORPORATE PAYMENT SYSTEMS Accounts Payable Outstanding AP Automation -15,705.50 08/22/2025 APA008185 US BANK NATIONAL ASSOCIATION Accounts Payable Outstanding AP Automation -256,628.71 08/22/2025 APA008186 USA BLUE BOOK Accounts Payable Outstanding AP Automation -5,372.50 08/22/2025 APA008187 VERIZON WIRELESS Accounts Payable Outstanding AP Automation -1,000.35 08/22/2025 APA008188 VESTIS Accounts Payable Outstanding AP Automation -39.69 08/22/2025 APA008189 WESTGATE PETROLEUM CO., INC. Accounts Payable Outstanding AP Automation -8,491.32 08/22/2025 APA008190 YOLO COUNTY FLOOD CONTROL Accounts Payable Outstanding AP Automation -3,124.80 08/22/2025 DFT0003986 CALPERS Accounts Payable Outstanding Bank Draft -3,810.80 08/22/2025 DFT0003987 CALPERS Accounts Payable Outstanding Bank Draft -3,877.31 08/22/2025 DFT0003988 CALPERS Accounts Payable Outstanding Bank Draft -5,889.20 08/22/2025 DFT0003989 CALPERS Accounts Payable Outstanding Bank Draft -6,048.80 08/22/2025 DFT0003990 CALPERS Accounts Payable Outstanding Bank Draft -3,831.02 08/22/2025 DFT0003991 CALPERS Accounts Payable Outstanding Bank Draft -6,790.48 08/22/2025 DFT0003992 CALPERS Accounts Payable Outstanding Bank Draft -514.79 08/22/2025 DFT0003993 CALPERS Accounts Payable Outstanding Bank Draft -1,395.66 08/22/2025 DFT0003994 CALPERS Accounts Payable Outstanding Bank Draft -50.22 08/22/2025 DFT0003995 CALPERS Accounts Payable Outstanding Bank Draft -6.91 08/22/2025 DFT0003996 IRS Accounts Payable Outstanding Bank Draft -5,007.68 08/22/2025 DFT0003997 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -6,652.57 08/22/2025 DFT0003998 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -2,062.79 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 7 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
08/22/2025 DFT0003999 IRS Accounts Payable Outstanding Bank Draft -16,585.83 08/22/2025 DFT0004000 IRS Accounts Payable Outstanding Bank Draft -303.80 08/25/2025 APA008191 4LEAF, INC. Accounts Payable Outstanding AP Automation -12,327.50 08/25/2025 APA008192 ADAMS ASHBY GROUP, LLC. Accounts Payable Outstanding AP Automation -1,000.00 08/25/2025 APA008193 APEX TECHNOLOGY MGMT, INC. Accounts Payable Outstanding AP Automation -168.75 08/25/2025 APA008194 AQUA PRODUCTS Accounts Payable Outstanding AP Automation -36.98 08/25/2025 APA008195 AT&T Accounts Payable Outstanding AP Automation -31.57 08/25/2025 APA008196 AT&T Accounts Payable Outstanding AP Automation -251.45 08/25/2025 APA008197 AT&T Accounts Payable Outstanding AP Automation -214.00 08/25/2025 APA008198 AT&T Accounts Payable Outstanding AP Automation -251.45 08/25/2025 APA008199 AT&T Accounts Payable Outstanding AP Automation -112.94 08/25/2025 APA008200 AT&T MOBILITY Accounts Payable Outstanding AP Automation -40.24 08/25/2025 APA008201 CALIF POLICE CHIEFS ASSN. Accounts Payable Outstanding AP Automation -1,200.00 08/25/2025 APA008202 CITY OF EUREKA Accounts Payable Outstanding AP Automation -22.00 08/25/2025 APA008203 CLEAR LAKE ENVIRONMENTAL RESEARCH CENTER Accounts Payable Outstanding AP Automation -3,936.00 08/25/2025 APA008204 COMPREHENSIVE DRUG TESTING, INC Accounts Payable Outstanding AP Automation -73.00 08/25/2025 APA008205 COUNTY OF LAKE-ANIMAL CONTROL Accounts Payable Outstanding AP Automation -68.75 08/25/2025 APA008206 COUNTY OF LAKE-SHERIFF Accounts Payable Outstanding AP Automation -193,064.80 08/25/2025 APA008207 FED EX Accounts Payable Outstanding AP Automation -8.95 08/25/2025 APA008208 GRANITE CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -894.34 08/25/2025 APA008209 HILLSIDE POWERSPORTS MARINE Accounts Payable Outstanding AP Automation -18,622.39 08/25/2025 APA008210 IMAGE SALES, INC. Accounts Payable Outstanding AP Automation -31.96 08/25/2025 APA008211 IT'S ABOUT TIME, INC Accounts Payable Outstanding AP Automation -645.75 08/25/2025 APA008212 JJACPA, INC. Accounts Payable Outstanding AP Automation -17,356.13 08/25/2025 APA008213 KELSEYVILLE TNT MINI STORAGE Accounts Payable Outstanding AP Automation -1,698.00 08/25/2025 APA008214 LAKE COUNTY RECORD BEE Accounts Payable Outstanding AP Automation -169.00 08/25/2025 APA008215 MATT MAZZEI CHEVROLET Accounts Payable Outstanding AP Automation -157.50 08/25/2025 APA008216 NAPA AUTO - LAKE PARTS Accounts Payable Outstanding AP Automation -1,266.28 08/25/2025 APA008217 NOR-CAL TELECOM Accounts Payable Outstanding AP Automation -180.00 08/25/2025 APA008218 PACE ENGINEERING, INC. Accounts Payable Outstanding AP Automation -36,418.00 08/25/2025 APA008219 PACE SUPPLY #03391-00 Accounts Payable Outstanding AP Automation -8.35 08/25/2025 APA008220 PAPE MACHINERY Accounts Payable Outstanding AP Automation -122.12 08/25/2025 APA008221 PITNEY BOWES GLOBAL FINANCIAL SVCS Accounts Payable Outstanding AP Automation -169.20 08/25/2025 APA008222 POLESTAR COMPUTERS Accounts Payable Outstanding AP Automation -5,553.00 08/25/2025 APA008223 PRECISION WIRELESS SERVICE Accounts Payable Outstanding AP Automation -350.00 08/25/2025 APA008224 RAINBOW AGRICULTURAL SERVICES Accounts Payable Outstanding AP Automation -144.78 08/25/2025 APA008225 REMIF Accounts Payable Outstanding AP Automation -113,061.40 08/25/2025 APA008226 REMIF Accounts Payable Outstanding AP Automation -179.95 08/25/2025 APA008227 SHRED-IT USA LLC Accounts Payable Outstanding AP Automation -218.94 08/25/2025 APA008228 THE SHOE BOX Accounts Payable Outstanding AP Automation -200.00 08/25/2025 APA008229 THE STANDARD INSURANCE COMPANY Accounts Payable Outstanding AP Automation -2,627.98 08/25/2025 APA008230 TRUIST GOVERNMENTAL FINANCE Accounts Payable Outstanding AP Automation -209,227.51 08/25/2025 APA008231 TUFTS POLYGRAPH & INVESTIGATIONS Accounts Payable Outstanding AP Automation -400.00 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 8 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
08/25/2025 APA008232 UNIVAR USA INC. Accounts Payable Outstanding AP Automation -6,301.76 08/25/2025 APA008233 USA BLUE BOOK Accounts Payable Outstanding AP Automation -4,797.83 08/25/2025 APA008234 VERIZON WIRELESS Accounts Payable Outstanding AP Automation -38.01 08/25/2025 APA008235 WESTGATE PETROLEUM CO., INC. Accounts Payable Outstanding AP Automation -296.98 08/25/2025 APA008236 WILLDAN FINANCIAL SERVICES Accounts Payable Outstanding AP Automation -2,015.00 08/28/2025 60872 AUSTIN ELDRED Accounts Payable Outstanding Check -972.00 08/28/2025 60873 COUNTY OF LAKE Accounts Payable Outstanding Check -50.00 08/28/2025 60874 LUANNE HAYES Accounts Payable Outstanding Check -50.00 08/28/2025 APA008237 AMERIGAS - 0920 Accounts Payable Outstanding AP Automation -680.30 08/28/2025 APA008238 AT&T CALNET3 Accounts Payable Outstanding AP Automation -141.37 08/28/2025 APA008239 DOKKEN ENGINEERING Accounts Payable Outstanding AP Automation -1,267.49 08/28/2025 APA008240 DUDEK Accounts Payable Outstanding AP Automation -4,961.10 08/28/2025 APA008241 EUREKA OXYGEN COMPANY Accounts Payable Outstanding AP Automation -63.89 08/28/2025 APA008242 IT'S ABOUT TIME, INC Accounts Payable Outstanding AP Automation -119.63 08/28/2025 APA008243 LEE'S SPORTING GOODS Accounts Payable Outstanding AP Automation -19.58 08/28/2025 APA008244 MANAGEMENT CONNECTIONS Accounts Payable Outstanding AP Automation -1,305.63 08/28/2025 APA008245 MEDIACOM Accounts Payable Outstanding AP Automation -316.79 08/28/2025 APA008246 OCCU-MED, LTD. Accounts Payable Outstanding AP Automation -1,190.00 08/28/2025 APA008247 O'REILLY AUTO PARTS Accounts Payable Outstanding AP Automation -31.05 08/28/2025 APA008248 PAVEMENT ENGINEERING INC. Accounts Payable Outstanding AP Automation -6,400.00 08/28/2025 APA008249 PG&E Accounts Payable Outstanding AP Automation -11.07 08/28/2025 APA008250 RAINBOW AGRICULTURAL SERVICES Accounts Payable Outstanding AP Automation -652.77 08/28/2025 APA008251 REUSER, INC. Accounts Payable Outstanding AP Automation -3,201.00 08/28/2025 APA008252 RICOH USA, INC. Accounts Payable Outstanding AP Automation -8.16 08/28/2025 APA008253 STAPLES BUSINESS ADVANTAGE Accounts Payable Outstanding AP Automation -287.90 08/28/2025 APA008254 UCC RENTALS Accounts Payable Outstanding AP Automation -2,250.00 08/28/2025 APA008255 URBAN TREE FARM NURSERY Accounts Payable Outstanding AP Automation -884.93 08/28/2025 APA008256 VISIT LAKE COUNTY CALIFORNIA Accounts Payable Outstanding AP Automation -14,869.63 08/28/2025 APA008257 ZUMAR INDUSTRIES, INC. Accounts Payable Outstanding AP Automation -1,614.79 09/05/2025 60875 AFLAC Accounts Payable Outstanding Check -572.27 09/05/2025 60876 CA STATE DISBURSEMENT UNIT Accounts Payable Outstanding Check -398.07 09/05/2025 60877 FRANCHISE TAX BOARD Accounts Payable Outstanding Check -50.00 09/05/2025 60878 LAKEPORT EMPLOYEE'S ASSOC Accounts Payable Outstanding Check -360.00 09/05/2025 60879 LPOA Accounts Payable Outstanding Check -605.00 09/05/2025 60880 NATIONWIDE RETIREMENT SOLUTION Accounts Payable Outstanding Check -1,075.00 09/05/2025 60881 VALIC - C/O JP MORGAN CHASE Accounts Payable Outstanding Check -2,313.92 09/05/2025 DFT0004001 CALPERS Accounts Payable Outstanding Bank Draft -3,545.32 09/05/2025 DFT0004002 CALPERS Accounts Payable Outstanding Bank Draft -3,607.18 09/05/2025 DFT0004003 CALPERS Accounts Payable Outstanding Bank Draft -5,919.58 09/05/2025 DFT0004004 CALPERS Accounts Payable Outstanding Bank Draft -6,079.99 09/05/2025 DFT0004005 CALPERS Accounts Payable Outstanding Bank Draft -3,868.57 09/05/2025 DFT0004006 CALPERS Accounts Payable Outstanding Bank Draft -6,857.04 09/05/2025 DFT0004007 CALPERS Accounts Payable Outstanding Bank Draft -514.79 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 9 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
09/05/2025 DFT0004008 CALPERS Accounts Payable Outstanding Bank Draft -1,395.66 09/05/2025 DFT0004009 CALPERS Accounts Payable Outstanding Bank Draft -49.29 09/05/2025 DFT0004010 CALPERS Accounts Payable Outstanding Bank Draft -6.91 09/05/2025 DFT0004011 IRS Accounts Payable Outstanding Bank Draft -4,628.30 09/05/2025 DFT0004012 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -5,461.43 09/05/2025 DFT0004013 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -1,912.96 09/05/2025 DFT0004014 IRS Accounts Payable Outstanding Bank Draft -14,166.38 09/05/2025 DFT0004015 IRS Accounts Payable Outstanding Bank Draft -210.80 09/08/2025 DFT0004016 CALPERS Accounts Payable Outstanding Bank Draft -700.00 09/09/2025 60882 DALE STOEBE Accounts Payable Outstanding Check -416.00 09/09/2025 60883 FORREST STOGNER Accounts Payable Outstanding Check -56.00 09/09/2025 60884 RYAN COOLEY Accounts Payable Outstanding Check -628.00 09/09/2025 60885 SHAUN JOHNSON Accounts Payable Outstanding Check -23.00 09/09/2025 60886 SWRCB Accounts Payable Outstanding Check -90.00 09/09/2025 60887 TODD STARKOVICH Accounts Payable Outstanding Check -220.00 09/09/2025 APA008258 ADVANCED SECURITY SYSTEMS Accounts Payable Outstanding AP Automation -114.00 09/09/2025 APA008259 ALPHA ANALYTICAL LABORATORIES Accounts Payable Outstanding AP Automation -813.00 09/09/2025 APA008260 AT&T CALNET3 Accounts Payable Outstanding AP Automation -381.41 09/09/2025 APA008261 AT&T CALNET3 Accounts Payable Outstanding AP Automation -296.29 09/09/2025 APA008262 AT&T CALNET3 Accounts Payable Outstanding AP Automation -247.97 09/09/2025 APA008263 AT&T CALNET3 Accounts Payable Outstanding AP Automation -93.57 09/09/2025 APA008264 DAVIS TIRE & AUTO REPAIR Accounts Payable Outstanding AP Automation -59.01 09/09/2025 APA008265 DEEP VALLEY SECURITY Accounts Payable Outstanding AP Automation -250.46 09/09/2025 APA008266 DEPT OF JUSTICE Accounts Payable Outstanding AP Automation -280.00 09/09/2025 APA008267 D-TAC K9 LLC Accounts Payable Outstanding AP Automation -7,500.00 09/09/2025 APA008268 EUREKA OXYGEN COMPANY Accounts Payable Outstanding AP Automation -161.63 09/09/2025 APA008269 FED EX Accounts Payable Outstanding AP Automation -8.95 09/09/2025 APA008270 FLOCK SAFETY Accounts Payable Outstanding AP Automation -3,000.00 09/09/2025 APA008271 GRANITE CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -921.13 09/09/2025 APA008272 IIMC Accounts Payable Outstanding AP Automation -135.00 09/09/2025 APA008273 INSURANCE AND BENEFITS TRUST OF PORAC Accounts Payable Outstanding AP Automation -283.50 09/09/2025 APA008274 IT'S ABOUT TIME, INC Accounts Payable Outstanding AP Automation -171.92 09/09/2025 APA008275 KIWANIS CLUB OF LAKEPORT Accounts Payable Outstanding AP Automation -175.00 09/09/2025 APA008276 LEE'S SPORTING GOODS Accounts Payable Outstanding AP Automation -707.40 09/09/2025 APA008277 MANAGEMENT CONNECTIONS Accounts Payable Outstanding AP Automation -5,899.00 09/09/2025 APA008278 NICK BARBIERI TRUCKING, LLC Accounts Payable Outstanding AP Automation -2,154.43 09/09/2025 APA008279 O'REILLY AUTO PARTS Accounts Payable Outstanding AP Automation -36.61 09/09/2025 APA008280 PAUL R. CURREN Accounts Payable Outstanding AP Automation -23,765.00 09/09/2025 APA008281 PEOPLE SERVICES, INC. Accounts Payable Outstanding AP Automation -200.00 09/09/2025 APA008282 PG&E Accounts Payable Outstanding AP Automation -454.94 09/09/2025 APA008283 PG&E Accounts Payable Outstanding AP Automation -346.69 09/09/2025 APA008284 PG&E Accounts Payable Outstanding AP Automation -154.71 09/09/2025 APA008285 PG&E Accounts Payable Outstanding AP Automation -51.16 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 10 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
09/09/2025 APA008286 PG&E Accounts Payable Outstanding AP Automation -801.74 09/09/2025 APA008287 PG&E Accounts Payable Outstanding AP Automation -23.82 09/09/2025 APA008288 PG&E Accounts Payable Outstanding AP Automation -924.56 09/09/2025 APA008289 PG&E Accounts Payable Outstanding AP Automation -1,603.59 09/09/2025 APA008290 PG&E Accounts Payable Outstanding AP Automation -1,677.45 09/09/2025 APA008291 PLAZA PAINT & SUPPLIES Accounts Payable Outstanding AP Automation -647.00 09/09/2025 APA008292 PRECISION WIRELESS SERVICE Accounts Payable Outstanding AP Automation -86.76 09/09/2025 APA008293 R3 CONSULTING GROUP, INC. Accounts Payable Outstanding AP Automation -395.00 09/09/2025 APA008294 RB PEST CONTROL Accounts Payable Outstanding AP Automation -2,000.00 09/09/2025 APA008295 RICOH - WELLS FARGO VENDOR FIN SVCS, LLC Accounts Payable Outstanding AP Automation -746.16 09/09/2025 APA008296 RICOH USA, INC. Accounts Payable Outstanding AP Automation -149.10 09/09/2025 APA008297 SHN CONSULTING ENGINEERS & GEO Accounts Payable Outstanding AP Automation -3,502.50 09/09/2025 APA008298 SKY SHOP AUTOBODY AND DETAILING Accounts Payable Outstanding AP Automation -2,000.00 09/09/2025 APA008299 STAPLES BUSINESS ADVANTAGE Accounts Payable Outstanding AP Automation -326.78 09/09/2025 APA008300 THATCHER COMPANY OF CA., INC. Accounts Payable Outstanding AP Automation -6,152.17 09/09/2025 APA008301 THE UPS STORE #5161 Accounts Payable Outstanding AP Automation -30.00 09/09/2025 APA008302 USA BLUE BOOK Accounts Payable Outstanding AP Automation -6,133.55 09/09/2025 APA008303 VERIZON WIRELESS Accounts Payable Outstanding AP Automation -556.78 09/09/2025 APA008304 VESTIS Accounts Payable Outstanding AP Automation -277.83 09/11/2025 APA008305 ENTERPRISE - EAN SERVICES, LLC Accounts Payable Outstanding AP Automation -265.24 09/11/2025 APA008306 GARTON TRACTOR Accounts Payable Outstanding AP Automation -110.47 09/11/2025 APA008307 HENRY REPAIRS HVAC INC. Accounts Payable Outstanding AP Automation -300.00 09/11/2025 APA008308 IRONEDGE GROUP Accounts Payable Outstanding AP Automation -509.74 09/11/2025 APA008309 LAKE COUNTY BROADBAND SOLUTIONS Accounts Payable Outstanding AP Automation -99.00 09/11/2025 APA008310 LEAGUE OF CALIF CITIES- REDWOOD EMPIRE DIVISION Accounts Payable Outstanding AP Automation -120.00 09/11/2025 APA008311 NUSO Accounts Payable Outstanding AP Automation -282.13 09/11/2025 APA008312 ONLINE INFORMATION SERVICES Accounts Payable Outstanding AP Automation -40.92 09/11/2025 APA008313 PG&E Accounts Payable Outstanding AP Automation -4,431.97 09/11/2025 APA008314 PITNEY BOWES BANK INC PURCHASE POWER Accounts Payable Outstanding AP Automation -1,067.58 09/11/2025 APA008315 RB PEST CONTROL Accounts Payable Outstanding AP Automation -140.00 09/11/2025 APA008316 RICOH - WELLS FARGO VENDOR FIN SVCS, LLC Accounts Payable Outstanding AP Automation -315.91 09/11/2025 APA008317 RICOH USA, INC. Accounts Payable Outstanding AP Automation -107.49 09/11/2025 APA008318 SEBIS DIRECT, INC. - PRINTING Accounts Payable Outstanding AP Automation -516.59 09/11/2025 APA008319 VERIZON WIRELESS Accounts Payable Outstanding AP Automation -955.84 09/11/2025 APA008320 VIKING SANDLASTING, LLC. Accounts Payable Outstanding AP Automation -1,925.00 09/11/2025 APA008321 WESTGATE PETROLEUM CO., INC. Accounts Payable Outstanding AP Automation -3,168.65 09/11/2025 APA008322 WILDA SHOCK Accounts Payable Outstanding AP Automation -1,500.00 09/15/2025 60888 LAKEPORT DISPOSAL, INC. Accounts Payable Outstanding Check -119,730.85 09/18/2025 60897 AUSTIN ELDRED Accounts Payable Outstanding Check -972.00 09/18/2025 60898 EDWARD OBAYASHI Accounts Payable Outstanding Check -275.00 09/18/2025 60899 WILDA SHOCK Accounts Payable Outstanding Check -100.00 09/18/2025 APA008323 ALPHA ANALYTICAL LABORATORIES Accounts Payable Outstanding AP Automation -2,195.00 09/18/2025 APA008324 AmWINS GROUP BENEFITS, INC. Accounts Payable Outstanding AP Automation -25,889.15 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 11 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
09/18/2025 APA008325 AT&T MOBILITY Accounts Payable Outstanding AP Automation -40.24 09/18/2025 APA008326 CLEAR LAKE ENVIRONMENTAL RESEARCH CENTER Accounts Payable Outstanding AP Automation -3,620.00 09/18/2025 APA008327 COMMUNITY DEVELOPMENT SERVICES Accounts Payable Outstanding AP Automation -1,125.00 09/18/2025 APA008328 DAVIS TIRE & AUTO REPAIR Accounts Payable Outstanding AP Automation -100.00 09/18/2025 APA008329 DEEP VALLEY SECURITY Accounts Payable Outstanding AP Automation -620.30 09/18/2025 APA008330 FOUNTAIN PEOPLE INC Accounts Payable Outstanding AP Automation -739.42 09/18/2025 APA008331 GHILOTTI CONSTRUCTION COMPANY Accounts Payable Outstanding AP Automation -82,284.68 09/18/2025 APA008332 GRAINGER Accounts Payable Outstanding AP Automation -123.77 09/18/2025 APA008333 HILLSIDE POWERSPORTS MARINE Accounts Payable Outstanding AP Automation -536.79 09/18/2025 APA008334 KELSEYVILLE TNT MINI STORAGE Accounts Payable Outstanding AP Automation -606.00 09/18/2025 APA008335 LAKE EVENT DESIGN & Accounts Payable Outstanding AP Automation -100.00 09/18/2025 APA008336 LEXIS NEXIS RISK SOLUTIONS Accounts Payable Outstanding AP Automation -206.00 09/18/2025 APA008337 MANAGEMENT CONNECTIONS Accounts Payable Outstanding AP Automation -3,647.60 09/18/2025 APA008338 MC ENGINEERING, INC Accounts Payable Outstanding AP Automation -282.50 09/18/2025 APA008339 McMASTER-CARR SUPPLY COMPANY Accounts Payable Outstanding AP Automation -241.71 09/18/2025 APA008340 MENDO MILL & LUMBER CO. Accounts Payable Outstanding AP Automation -2,879.24 09/18/2025 APA008341 PACE ENGINEERING, INC. Accounts Payable Outstanding AP Automation -55,979.25 09/18/2025 APA008342 PLAZA PAINT & SUPPLIES Accounts Payable Outstanding AP Automation -283.56 09/18/2025 APA008343 RAINBOW AGRICULTURAL SERVICES Accounts Payable Outstanding AP Automation -41.99 09/18/2025 APA008344 RB PEST CONTROL Accounts Payable Outstanding AP Automation -310.00 09/18/2025 APA008345 REMIF Accounts Payable Outstanding AP Automation -110,378.60 09/18/2025 APA008346 SANTANA'S COTTAGE Accounts Payable Outstanding AP Automation -410.53 09/18/2025 APA008347 SHRED-IT USA LLC Accounts Payable Outstanding AP Automation -330.91 09/18/2025 APA008348 SUTTER LAKESIDE HOSPITAL Accounts Payable Outstanding AP Automation -25.00 09/18/2025 APA008349 THE UPS STORE #5161 Accounts Payable Outstanding AP Automation -30.00 09/18/2025 APA008350 TRI-CITIES ANSWERING SERVICE Accounts Payable Outstanding AP Automation -313.31 09/18/2025 APA008351 TUFTS POLYGRAPH & INVESTIGATIONS Accounts Payable Outstanding AP Automation -400.00 09/18/2025 APA008352 U.S. BANK CORPORATE PAYMENT SYSTEMS Accounts Payable Outstanding AP Automation -11,429.71 09/18/2025 APA008353 VERIZON WIRELESS Accounts Payable Outstanding AP Automation -38.01 09/18/2025 APA008354 VESTIS Accounts Payable Outstanding AP Automation -39.69 09/18/2025 APA008355 WMH CORPORATION Accounts Payable Outstanding AP Automation -8,687.50 09/18/2025 APA008356 YOLO COUNTY FLOOD CONTROL Accounts Payable Outstanding AP Automation -449.37 09/19/2025 60889 AFLAC Accounts Payable Outstanding Check -572.27 09/19/2025 60890 CA STATE DISBURSEMENT UNIT Accounts Payable Outstanding Check -398.07 09/19/2025 60891 FRANCHISE TAX BOARD Accounts Payable Outstanding Check -50.00 09/19/2025 60892 LAKEPORT EMPLOYEE'S ASSOC Accounts Payable Outstanding Check -360.00 09/19/2025 60893 LEGALSHIELD Accounts Payable Outstanding Check -357.25 09/19/2025 60894 LPOA Accounts Payable Outstanding Check -605.00 09/19/2025 60895 NATIONWIDE RETIREMENT SOLUTION Accounts Payable Outstanding Check -1,075.00 09/19/2025 60896 VALIC - C/O JP MORGAN CHASE Accounts Payable Outstanding Check -2,313.92 09/19/2025 DFT0004017 CALPERS Accounts Payable Outstanding Bank Draft -4,089.67 09/19/2025 DFT0004018 CALPERS Accounts Payable Outstanding Bank Draft -4,161.05 09/19/2025 DFT0004019 CALPERS Accounts Payable Outstanding Bank Draft -5,939.48 Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 12 of 13
Cleared
Date Number Description Module Status Type Amount
Issued
Date
09/19/2025 DFT0004020 CALPERS Accounts Payable Outstanding Bank Draft -6,100.43 09/19/2025 DFT0004021 CALPERS Accounts Payable Outstanding Bank Draft -3,841.91 09/19/2025 DFT0004022 CALPERS Accounts Payable Outstanding Bank Draft -6,809.79 09/19/2025 DFT0004023 CALPERS Accounts Payable Outstanding Bank Draft -514.79 09/19/2025 DFT0004024 CALPERS Accounts Payable Outstanding Bank Draft -1,395.66 09/19/2025 DFT0004025 CALPERS Accounts Payable Outstanding Bank Draft -49.29 09/19/2025 DFT0004026 CALPERS Accounts Payable Outstanding Bank Draft -6.91 09/19/2025 DFT0004027 IRS Accounts Payable Outstanding Bank Draft -4,692.02 09/19/2025 DFT0004028 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -5,592.23 09/19/2025 DFT0004029 CA EMP DEVELOPMENT DEPT Accounts Payable Outstanding Bank Draft -1,932.11 09/19/2025 DFT0004030 IRS Accounts Payable Outstanding Bank Draft -14,391.64 09/19/2025 DFT0004031 IRS Accounts Payable Outstanding Bank Draft -285.20 Bank Account 15-0352000798 Total: (478) -6,108,286.96
Report Total: (478) -6,108,286.96
Bank Transaction Report Issued Date Range: -
9/22/2025 3:44:50 PM Page 13 of 13
Summary
Bank Account Count Amount
15-0352000798 POOLED CASH BANK 478 -6,108,286.96
Report Total: 478 -6,108,286.96
Cash Account Count Amount
998 998-0000-101000 POOLED CASH - WEST AMERICA 478 -6,108,286.96 Report Total: 478 -6,108,286.96
Transaction Type Count Amount
AP Automation 338 -5,540,339.25
AP Automation Reversal 1 3,650.00
Bank Draft 76 -299,160.92
Check 63 -272,436.79
Report Total: 478 -6,108,286.96
Meeting Date: 10/21/2025 Page 1 Agenda Item #IV.D

CITY OF LAKEPORT
City Council
City of Lakeport Municipal Sewer District
Lakeport Redevelopment Successor Agency
Lakeport Industrial Development Agency
Municipal Financing Agency of Lakeport

STAFF REPORT
RE: Update to Master Salary Schedule MEETING DATE: 10/21/2025 SUBMITTED BY: Kelly Buendia, Administrative Services Director PURPOSE OF REPORT: Information only Discussion Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

The City Council is being asked to approve updates to the Master Salary Schedule generated by the recently adopted Memorandum of Understanding with the Lakeport Police Officers’ Association.

BACKGROUND/DISCUSSION:

CalPERS, pursuant to its interpretation of California Code of Regulations, title 2, section 570.5, recommends all CalPERS employers maintain their compensation levels in a publicly available pay schedule, approved and adopted by the governing body.

The City Council approved a Memorandum of Understanding with the Lakeport Police Officers’ Association via Resolution 3002 (2025) on 9/16/2025, which included changes to salary retroactive to the first pay period after 7/1/2025. These changes are reflected in the attached Master Salary Schedule and there are no other negotiated cost of living adjustments impacting the salary schedule at this time.

In compliance with California Code of Regulations, title 2, section 570.5, the revised schedule will be made publicly available on the City’s website.

OPTIONS:

The Council could deny this request and provide other direction to staff.

FISCAL IMPACT:

There is no fiscal impact in approving salary schedules. Budgeted Item? Yes No Budget Adjustment Needed? Yes No If yes, amount of appropriation increase:

Affected fund(s): General Fund Water OM Fund Sewer OM Fund Other:

Meeting Date: 10/21/2025 Page 2 Agenda Item #IV.D
COUNCIL PRIORITIES:
☐ Priority #1: Public Safety & Crisis Response
☐ Priority #2: Disaster Resiliency
☒ Priority #3: Good Governance & Fiscal Stability
☐ Priority #4: Capital Infrastructure Improvement
☐ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Move to approve a Resolution rescinding Resolution 2996 (2025) and revising the Master Pay Schedule in conformance with California Code of Regulations, Title 2, Section 570.5.

Attachments:

1. Resolution Rescinding Resolution 2996 (2025) and Revising the Master Pay Schedule in Conformance with California Code of Regulations Title 2, Section 570.5

2. Master Salary Schedule

Page 1 ends

191565.1
RESOLUTION NO. XXXX (2025)

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF LAKEPORT RESCINDING RESOLUTION 2966 (2025) AND REVISING THE

MASTER PAY SCHEDULE IN CONFORMANCE WITH CALIFORNIA
CODE OF REGULATIONS, TITLE 2, SECTION 570.5
WHEREAS, The City Council approved a Memorandum of Understanding with the Lakeport Police Officers’ Association via Resolution 3002 (2025) on 9/16/2025, which included changes to salary retroactive to the first pay period after 7/1/2025; and WHEREAS, the California Public Employees’ Retirement System (CalPERS) has requested all CalPERS employers list their compensation levels on one document, approved and adopted by the governing body, in accordance with title 2 of the California Code of Regulations, section 570.5, and meeting all of the following requirements thereof:

1. Has been duly approved and adopted by the employer's governing body in accordance with requirements of applicable public meetings laws;

2. Identifies the position title for every employee position;

3. Shows the pay rate for each identified position, which may be stated as a single amount or as multiple amounts within a range;

4. Indicates the time base, including, but not limited to, whether the time base is hourly, daily, bi-weekly, monthly, bi-monthly, or annually;

5. Is posted at the office of the employer or immediately accessible and available for public review from the employer during normal business hours or posted on the employer's internet website;

6. Indicates an effective date and date of any revisions;

7. Is retained by the employer and available for public inspection for not less than five years; and

8. Does not reference another document in lieu of disclosing the pay rate.

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

SECTION 1.

Resolution 2966 (2025) is rescinded.

SECTION 2.

The City Council affirms the previously approved separate compensation levels for represented Bargaining Unit positions and the Compensation Plans for the unrepresented positions through, by and with the adoption of the single Master Pay Schedule attached hereto as Exhibit A.

SECTION 3. The City Council affirms the single Master Pay Schedule attached hereto meets all of the requirements of title 2 of the California Code of Regulations, section 570.5, including but

Page 2 ends

191565.1
not limited to directing staff to post it at the City, make it immediately available for public review during normal business hours and/or post on the City’s internet website and be retained by the City and available for public inspection for not less than five years.

DULY AND REGULARLY ADOPTED on this 21st day of October, 2025, by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:
________________________________
KIM COSTA, Mayor
ATTEST:
______________________________
KELLY BUENDIA, City Clerk
Job Classification Class Range Unit A B C D E F
Office Specialist GU108 LEA 2,787 2,926 3,072 3,226 3,387 3,556 Parks Maintenance Worker I GU124 LEA 3,018 3,169 3,327 3,493 3,668 3,851 Equipment Mechanic I GU131 LEA 3,124 3,280 3,444 3,616 3,797 3,987 Maintenance Worker I GU138 LEA 3,236 3,398 3,568 3,746 3,933 4,130 Parks Maintenance Worker II GU139 LEA 3,252 3,415 3,586 3,765 3,953 4,151 Police Records & Evidence Clerk GU139 LEA 3,252 3,415 3,586 3,765 3,953 4,151 Administrative Specialist I GU140 LEA 3,268 3,431 3,603 3,783 3,972 4,171 Financial Services Specialist I GU140 LEA 3,268 3,431 3,603 3,783 3,972 4,171 Deputy City Clerk I GU156 LEA 3,540 3,717 3,903 4,098 4,303 4,518 Utility Operator I GU162 LEA 3,648 3,830 4,022 4,223 4,434 4,656 Financial Services Specialist II GU165 LEA 3,702 3,887 4,081 4,285 4,499 4,724 Maintenance Worker II GU165 LEA 3,702 3,887 4,081 4,285 4,499 4,724 Engineering Technician I GU172 LEA 3,835 4,027 4,228 4,439 4,661 4,894 * Administrative Specialist II GU174 LEA 3,873 4,067 4,270 4,484 4,708 4,943 Equipment Mechanic II GU175 LEA 3,892 4,087 4,291 4,506 4,731 4,968 Assistant Planner GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Deputy City Clerk II GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Maintenance Worker III GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Parks Leadworker GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Permit Technician GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Utility Operator/MWII GU181 LEA 4,011 4,212 4,423 4,644 4,876 5,120 Utility Operator II GU196 LEA 4,322 4,538 4,765 5,003 5,253 5,516 Engineering Technician II GU197 LEA 4,344 4,561 4,789 5,028 5,279 5,543 Parks Maintenance Foreman GU197 LEA 4,344 4,561 4,789 5,028 5,279 5,543 GIS/Asset Management Technician GU199 LEA 4,388 4,607 4,837 5,079 5,333 5,600 * Administrative Analyst GU206 LEA 4,543 4,770 5,009 5,259 5,522 5,798 Housing Specialist GU206 LEA 4,543 4,770 5,009 5,259 5,522 5,798 Building Inspector GU213 LEA 4,704 4,939 5,186 5,445 5,717 6,003 Financial Services Specialist III GU213 LEA 4,704 4,939 5,186 5,445 5,717 6,003 Police Records Supervisor GU219 LEA 4,848 5,090 5,345 5,612 5,893 6,188 Utility Operator III GU221 LEA 4,896 5,141 5,398 5,668 5,951 6,249 Wastewater Systems Supervisor I GU223 LEA 4,945 5,192 5,452 5,725 6,011 6,312 Water Operations Supervisor I GU223 LEA 4,945 5,192 5,452 5,725 6,011 6,312 * Deputy City Clerk III - Records Supervisor GU233 LEA 5,198 5,458 5,731 6,018 6,319 6,635 Associate Planner GU233 LEA 5,198 5,458 5,731 6,018 6,319 6,635 Electrical Mechanical Technician (EMT) GU233 LEA 5,198 5,458 5,731 6,018 6,319 6,635 Projects Coordinator GU233 LEA 5,198 5,458 5,731 6,018 6,319 6,635 Public Works Foreman GU240 LEA 5,383 5,652 5,935 6,232 6,544 6,871 Utilities Underground Superviosr GU240 LEA 5,383 5,652 5,935 6,232 6,544 6,871 Wastewater Systems Supervisor II GU244 LEA 5,491 5,766 6,054 6,357 6,675 7,009 Water Operations Supervisor II GU244 LEA 5,491 5,766 6,054 6,357 6,675 7,009 Steps

CITY OF LAKEPORT

MASTER PAY SCHEDULE

MONTHLY RATES WITH STEPS
Effective First Pay Period after 7/1/2025
Police Officer I PO200 POA 5,630 5,912 6,208 6,518 6,844 7,186 Police Officer II PO215 POA 6,067 6,370 6,689 7,023 7,374 7,743 Compliance Officer I MM102 UM 6,465 6,788 7,127 7,483 7,857 n-a Government Accountant MM102 UM 6,465 6,788 7,127 7,483 7,857 n-a Planning Services Manager MM102 UM 6,465 6,788 7,127 7,483 7,857 n-a Water/Wastewater Treatment Supervisor GU279 LEA 6,538 6,865 7,208 7,568 7,946 8,343 Police Officer III PO234 POA 6,670 7,004 7,354 7,722 8,108 8,513 Police Detective PO245 POA 7,047 7,399 7,769 8,157 8,565 8,993 Police Sergeant PO245 POA 7,047 7,399 7,769 8,157 8,565 8,993 Compliance Officer II MM122 UM 7,143 7,500 7,875 8,269 8,682 n-a Public Works Superintendent I MM122 UM 7,143 7,500 7,875 8,269 8,682 n-a Building Official MM123 UM 7,179 7,538 7,915 8,311 8,727 n-a Public Works Superintendent II MM137 UM 7,697 8,082 8,486 8,910 9,356 n-a Utilities Superintendent MM142 UM 7,892 8,287 8,701 9,136 9,593 n-a Police Lieutenant MM151 UM 8,254 8,667 9,100 9,555 10,033 n-a Public Works Director MM164 UM 8,808 9,248 9,710 10,196 10,706 n-a Utilities Director MM164 UM 8,808 9,248 9,710 10,196 10,706 n-a Police Captain MM170 UM 9,077 9,531 10,008 10,508 11,033 n-a Administrative Services Dir./City Clerk MM173 UM 9,213 9,674 10,158 10,666 11,199 n-a Finance Director MM173 UM 9,213 9,674 10,158 10,666 11,199 n-a Community Development Director MM177 UM 9,399 9,869 10,362 10,880 11,424 n-a Assistant City Manager MM190 UM 10,028 10,529 11,055 11,608 12,188 n-a Police Chief MM202 UM 10,647 11,179 11,738 12,325 12,941 n-a City Engineer/Public Works Director MM229 UM 12,181 12,790 13,430 14,102 14,807 n-a City Manager n-a contract 13,860 n-a n-a n-a n-a n-a

HOURLY AT-WILL EMPLOYEES
Police Officer Trainee n-a n-a
LEA = Lakeport Employees' Association, salaries effective 7/6/2024 - Resolution No. 2961 (2024) UM = Unrepresented Management, salaries effective 7/5/2025 - Resolution No. 2973 (2024) POA = Lakeport Police Officers' Association, salaries effective 7/6/2025 - Resolution No. 3002 (2025) City Manager contract amended effective 3/4/2025, Resolution No. 2982 (2025) *Classifications may include Confidential employees - Resolution 2657 (2018) Schedule Revised 10/21/2025
$19.50 - $24.89 per hour
Meeting Date: 10/21/2025 Page 1 Agenda Item #IV.E

CITY OF LAKEPORT
City Council
City of Lakeport Municipal Sewer District
Lakeport Redevelopment Successor Agency
Lakeport Industrial Development Agency
Municipal Financing Agency of Lakeport

STAFF REPORT
RE: Notice of Completion for the 2024 Water & Sewer Main Replacement Project
MEETING DATE:

October 21, 2025
SUBMITTED BY: Paul Harris, Utilities Director
PURPOSE OF REPORT: Information only Discussion Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

The City Council is being asked to adopt a resolution accepting the 2024 Water & Sewer Main Replacement Project, Bid 23-05, as complete and authorize the City Manager to file a Notice of Completion.

BACKGROUND/DISCUSSION:

On June 4, 2024, the City Council awarded a construction contract to Ghilotti Construction Company, for the 2024 Water & Sewer Main Replacement Project, Bid 23-05, in the amount of $8,042,049.00.

The project scope included utility infrastructure upgrades and replacements on Lakeshore Blvd, Sayre St., Jones St., Tunis St., Tenth St., Armstrong St., Martin St., Lakeport Blvd, K St., and Forbes St.

In summary, 10,216 lineal feet of water mainline was replaced, 130 water services were replaced and 6,508 lineal feet of new sanitary sewer pipes were installed.

The City of Lakeport Public Works Department has reviewed the project and determined that it has been completed in substantial compliance with the project plans and specifications. The total cost of the construction contract came out to $8,049,308.19. Although there were 23 change orders, the final cost was only $7,259.19 over the original contract. The change order summary is attached.

OPTIONS:

No other options recommended
FISCAL IMPACT:

None $ Budgeted Item? Yes No
Budget Adjustment Needed? Yes No If yes, amount of appropriation increase: $ Affected fund(s): General Fund Water OM Fund Sewer OM Fund Other:

Comments:

Meeting Date: 10/21/2025 Page 2 Agenda Item #IV.E
COUNCIL PRIORITIES:
☐ Priority #1: Public Safety & Crisis Response
☐ Priority #2: Disaster Resiliency
☐ Priority #3: Good Governance & Fiscal Stability
☒ Priority #4: Capital Infrastructure Improvement
☐ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Move to adopt the resolution accepting construction of the 2024 Water & Sewer Main Replacement Project, by Ghilotti Construction Company and authorize the filing of the Notice of Completion.

Attachments: 1) Change Order Summary
2) Resolution
3) Notice of Completion

Item # GCC RFC #
Contract
Time CCO Total Date signed Revised Total
Original
Contract 225 $8,042,049.00
EZ St Temp Patch 0 ($25,370.00) 8/22/2024 $8,016,679.00 SSMH #2k-Delete $8,016,679.00
WV Cluster Martin-Main $8,016,679.00
CCO 2 Upsize Meter Boxes 2 0 $5,625.31 ($19,744.69) 9/30/2024 $8,022,304.31 CCO 3 Modify SSMH 10L 5 0 $19,540.91 ($203.78) 10/3/2024 $8,041,845.22 CCO 4 K St Sewer Revisions 6 4 $101,072.03 $100,868.25 10/14/2024 $8,142,917.25 CCO 5 Forbes St Waterline 0 $2,724.84 $103,593.09 10/27/2024 $8,145,642.09 CCO 6 Lower Inverts 10M & 12M 1 $24,035.02 $127,628.11 11/11/2024 $8,169,677.11 CCO 7
Misc Extra Work and n36
Boxes
8, 9, 10.1,
11, 13 0 $12,950.62 $140,578.73 12/23/2024 $8,182,627.73 CCO 8
Martin St Pipe Burst
Revisions 7 0 ($63,037.61) $77,541.12 1/22/2025 $8,119,590.12 CCO 9 Waterline Break On Martin $21,781.97 $99,323.09 1/25/2025 $8,141,372.09 CCO 10 Sewer Spill Cleanup 0 (1,508.25) $97,814.84 2/11/2025 $8,139,863.84 CCO 11
Water Main Crossing RCP,
Half Offset 17,18, 19.1 0 (4,852.64) $92,962.20 2/14/2025 $8,135,011.20 CCO 12 Correction to CCO 11 0 (2,484.00) $90,478.20 2/27/2025 $8,132,527.20 CCO 13 Lakeport Blvd Claim 0 51,222.64 $141,700.84 2/27/2025 $8,183,749.84 CCO 14 Martin St LOP Claim 2 19,995.00 $161,695.84 3/17/2025 $8,203,744.84 CCO 15 Misc Extra Work 0 16,347.06 $178,042.90 5/19/2025 $8,220,091.90 CCO 16 SD at Martin Lift Station 2
24,844.49 $202,887.39 5/27/2025 $8,244,936.39
CCO 17 Delete Pavement Markings 0 ($86,250.00) $116,637.39 7/14/2025 $8,158,686.39 CCO 18 Delete Trench Paving 0 ($79,549.00) $37,088.39 7/17/2025 $8,079,137.39 CCO 19
Point Repairs SS Lakeport
Blvd 0 $4,199.58 $41,287.97 7/27/2025 $8,083,336.97
CCO 20 Misc Extra Work 1 $7,907.18 $49,195.15 7/27/2025 $8,091,244.15 CCO 21
Delete Vacuum Testing and
Paving-Martin 0 ($12,043.08) $37,152.07 9/3/2025 $8,079,201.07 CCO 22 Additional Point Repairs 3 $24,509.97 $61,662.04 9/15/2025 $8,103,711.04 CCO 23 Balancing 0 ($54,402.85) $7,259.19 9/23/2025 $8,049,308.19 Final Contract Cost $8,049,308.19
2024 Water & Sewer Main Replacement Bid No 23-05
Contract Change Order Summary
CCO 1
RESOLUTION NO. XXXX (2025)

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF LAKEPORT ACCEPTING CONSTRUCTION OF THE 2024 WATER & SEWER MAIN REPLACEMENT PROJECT, BID NO 23-05,

AND AUTHORIZINGTHE FILING OF THE NOTICE OF COMPLETION
WHEREAS, the final inspection of the 2024 Water & Sewer Main Replacement Project, Bid No 23-05, was made by the City of Lakeport’s Public Works Department; and
WHEREAS, it was determined that the work for this project has been completed in substantial compliance with the project plans and specifications.

NOW, THEREFORE, BE IT RESOLVED BY THE CITY COUNCIL OF THE CITY OF LAKEPORT AS FOLLOWS:

1. The City Council hereby accepts the work as completed on the 2024 Water & Sewer Main Replacement Project, Bid No 23-05.

2. The City Manager is authorized and directed to execute the Notice of Completion to be filed with the County of Lake.

The foregoing Resolution was adopted at a regular meeting of the City Council of the City of Lakeport held on the on the 21st day of October, 2025 by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:

APPROVED:
_______________________________
Kim Costa, Mayor
City of Lakeport
ATTEST:
_________________________________
Kelly Buendia, City Clerk
City of Lakeport

4.E.3 -W&S Notice of Completion

RECORDING REQUESTED BY
City of Lakeport

AND WHEN RECORDED MAIL THIS DEED,
UNLESS OTHERWISE SHOWN BELOW.

MAIL TAX STATEMENTS TO:

City of Lakeport Attn: Olivia Grupp
225 Park Street
Lakeport, CA 95453
Complimentary recording request pursuant to
government code § 27383
SPACE ABOVE THIS LINE FOR RECORDER’S USE
Notice of Completion
NOTICE is hereby given that:

1. The Undersigned is owner of the interest stated below in the property hereinafter described:

2. The NAME (including that of the undersigned), ADDRESS and NATURE OF TITLE of every person owning any interest in such property is as follows:

City of Lakeport 225 Park St, Lakeport, CA 95453 Fee Simple (NAME OF UNDERSIGNED)

3. The names and addresses of the transferors of the undersigned owner: (to be shown if the undersigned is a successor in interest of the owner who caused the improvement to be constructed, etc.)

4. A work of improvement on the property hereinafter described was COMPLETED ON 8/21/2025

5. The name of the CONTRACTOR for such work of improvement was Ghilotti Construction Company, 246 Ghilotti Ave
Santa Rosa, CA 95407
(If no Contractor, insert “NONE”

6. The property on which said work of improvement was completed is in the City of Lakeport , county of Lake State of California, and is described as follows: Installation of new water and sewer main line pipe and service connections.

EXEMPT FROM NOTARY ACKNOWLEDGEMENT REQUIREMENTS PER GOVERNMENT CODE §27287 & CIVIL CODE §9208

7. The street address of said property is: Various locations throughout the City of Lakeport Dated:

Signature of
Owner or Owners }
Kevin M. Ingram, City Manager
Verification for NON-INDIVIDUAL owner: I, the undersigned, declare under penalty of perjury under the laws of the State of California that I am the City Manager of the aforesaid interest or estate in (“PRESIDENT, PARTNER, MANAGER, AGENT, ETC.”
the property described in the above notice; that I have read the said notice, that I know and understand the contents thereof, and that the facts stated therein are true and correct.

Date and Place (Signature of person signing on behalf of owner)) Meeting Date: 10/21/2025 Page 1 Agenda Item # 4.F
407103.1

CITY OF LAKEPORT
City Council
City of Lakeport Municipal Sewer District
Lakeport Redevelopment Successor Agency
Lakeport Industrial Development Authority
Municipal Financing Agency of Lakeport

STAFF REPORT
RE: A resolution of the City Council of the City of Lakeport authorizing the repeal and replacement of Resolution No. 3000 (2025), entering into a funding agreement with the California Department of Fish and Wildlife (CDFW), accepting grant funds, and authorizing the City Manager or Public Works Director to execute all documents for the Oil Spill Response Equipment Staging Grant in Lake County.

MEETING DATE: 10/21/2025
SUBMITTED BY: Ron Ladd, Public Works Director
PURPOSE OF REPORT: Information only Discussion Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

Adopt a resolution repealing and replacing Resolution No. 3000 and authorizing the City Manager, or designee, to enter into a funding agreement with the California Department of Fish and Wildlife, Office of Spill Prevention and Response (OSPR); accept grant funds in an amount not to exceed $10,000; and execute all related documents, including amendments and reimbursement requests.

BACKGROUND/DISCUSSION:

The California Department of Fish and Wildlife, Office of Spill Prevention and Response (OSPR), administers the Oil Spill Response Equipment Staging Grant to enhance local spill readiness. The City submitted an application for $10,000 to replenish and enhance spill response equipment staged at the Public Works Corporation Yard (591 Martin Street), ensuring rapid deployment and initial containment capability on Clear Lake and other city waterways.

On September 2, 2025, the City Council adopted Resolution No. 3000 authorizing acceptance of the OSPR grant. However, following CDFW’s final review, minor administrative corrections were identified in the resolution language, including clarification of the grant title (“Oil Spill Response Equipment Staging Grant”) and alignment of the authorizing and CEQA language with the State’s required resolution format.

CDFW has since provided a corrected version incorporating these adjustments and has confirmed acceptance of the City Attorney’s prior revisions. Adoption of this updated resolution will repeal and replace Resolution No. 3000 in its entirety to ensure consistency with the approved CDFW template and facilitate final execution of the funding agreement.

The grant will fund replenishment of critical spill response materials, including approximately 400 ft of containment boom, six personal flotation devices, staff PPE, two anchors, one WaterGate barrier, and absorbent pads. These supplies support rapid deployment by trained Public Works staff using existing City resources (e.g., work boat, vac truck).

Meeting Date: 10/21/2025 Page 2 Agenda Item # 4.F
407103.1
OPTIONS:

1. Adopt the resolution as presented.

2. Adopt the resolution with modifications and provide direction to staff.

3. Take no action.

FISCAL IMPACT:

None (Grant Funded) $ Budgeted Item? Yes No
Budget Adjustment Needed? Yes No If yes, amount of appropriation increase: $ 10,000 Affected fund(s): General Fund Water OM Fund Sewer OM Fund Other: Special Revenue/Grant Comments:

This is a reimbursement grant; no local match; no General Fund impact.

COUNCIL PRIORITIES:
☒ Priority #1: Public Safety & Crisis Response
☒ Priority #2: Disaster Resiliency
☒ Priority #3: Good Governance & Fiscal Stability
☐ Priority #4: Capital Infrastructure Improvement
☒ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Move to repeal and replace Resolution No. 3000 (2025), entering into a funding agreement with the California Department of Fish and Wildlife (CDFW), accepting grant funds, and authorizing the City Manager, or Public Works Director, to execute all documents for the Oil Spill Response Equipment Staging Grant, Lake County Attachments: 1. Resolution 3000 (2025) – Previously Approved Resolution

2. Corrected Repeal and Replace Resolution

3. Grant Agreement – "Exhibit A"

408200.2
RESOLUTION NO. ____ (2025)

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF LAKEPORT AUTHORIZING REPEALING AND REPLACING RESOLUTION NO. 3000 (2025),

ENTERING INTO A FUNDING AGREEMENT WITH THE CALIFORNIA DEPARTMENT

OF FISH AND WILDLIFE (CDFW), ACCEPTING GRANT FUNDS, AND AUTHORIZING

THE CITY MANAGER, OR PUBLIC WORKS DIRECTOR, TO EXECUTE ALL

DOCUMENTS FOR THE OIL SPILL RESPONSE EQUIPMENT STAGING GRANT,

LAKE COUNTY
WHEREAS, the California Department of Fish and Wildlife (CDFW) administers the Oil Spill Response Equipment Staging Grant program; and
WHEREAS, the City of Lakeport submitted an application requesting $10,000 to replenish and enhance oil spill response equipment to be staged at the City’s Public Works Corporation Yard at 591 Martin Street, Lakeport, California; and
WHEREAS, prior to executing a funding agreement, CDFW requires the City to adopt a resolution authorizing an official to sign the funding agreement, any amendments, payment/disbursement requests, and related documents, and to carry out other necessary project-related activities; and
WHEREAS, on September 2, 2025, the City Council adopted Resolution No. 3000, which referenced the Oil Spill Response Equipment Staging Grant incorrectly; WHEREAS, it is now necessary and desirable for the City to repeal and replace Resolution No.3000 to correct this oversight and accept and authorize the Oil Spill Response Equipment Staging Grant.

NOW, THEREFORE, BE IT RESOLVED that the City Council of the City of Lakeport hereby:

1. Repeals and replaces Resolution No.3000, adopted on September 2, 2025, in its entirety; and

2. Authorizes the city to enter into a funding agreement with CDFW, attached hereto as Exhibit “A” and incorporated herein by reference (the “Funding Agreement”), and to accept and expend grant funds for eligible equipment and uses in an amount not to exceed $10,000 for the Oil Spill Response Equipment Staging Grant project; and

3. Authorizes the City Manager, or Public Works Director, to conduct all negotiations and to sign for and on behalf of the City of Lakeport the Funding Agreement, any amendments thereto, and all related documents, including, but not limited to, payment/disbursement requests and reports necessary for the completion of the grant scope; and
408200.2

4. Agrees to comply with all applicable federal, state, and local laws, regulations, and program requirements governing the Oil Spill Response Equipment Staging Grant; and

5. Approves and finds the approval of the Funding Agreement and acceptance of the CDFW Oil Spill Response Equipment Staging, Lake County exempt from the California Environmental Quality Act pursuant to CEQA Guidelines sections 15378(b)(4) (governmental fiscal activities which do not involve any commitment to any specific project which may result in a potentially significant physical impact on the environment), 15307 (actions by regulatory agencies for protection of natural resources), 15308 (actions by regulatory agencies for protection of the environment), and 15061(b)(3) (common sense exemption where it can be seen with certainty that there is no possibility that the activity in question may have a significant event on the environment); and

6. Be it further resolved and ordered, that any and all actions, whether previously or subsequently taken by the City of Lakeport, which are consistent with the intent and purposes of the foregoing resolution, shall be, and hereby are, in all respects, ratified, approved, and confirmed.

DULY AND REGULARLY ADOPTED at a regular meeting of the City Council of the City of Lakeport on this 21st day of October, 2025, by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:
____________________________________
KIM COSTA, Mayor
ATTEST:
______________________________
KELLY BUENDIA, City Clerk
State of California - Natural Resources Agency GAVIN NEWSOM, Governor DEPARTMENT OF FISH AND WILDLIFE CHARLTON H. BONHAM, Director P.O. Box 944209
Sacramento, CA 94244-2090
www.wildlife.ca.gov
(Template v. 01/04/2024)

OFFICE OF SPILL PREVENTION AND RESPONSE

OIL SPILL RESPONSE EQUIPMENT STAGING, LAKE COUNTY
GRANT AGREEMENT NUMBER – Q2575070
GRANTOR: State of California, acting by and through
The California Department of Fish and Wildlife
P.O. Box 944209
Sacramento, CA 94244-2090
GRANTEE: City of Lakeport
225 Park Street
Lakeport, CA 95453
SECTION 1 – LEGAL BASIS OF AWARD
Pursuant to Government Code 8670.8.3, the California Department of Fish and Wildlife (CDFW or Grantor) is authorized to enter into this Grant Agreement (Agreement) and to make an award to the City of Lakeport (Grantee) for the purposes set forth herein. The Grantee accepts the grant on the terms and conditions of this Agreement. Accordingly, the Grantor and the Grantee (Parties) hereby agree as follows:

SECTION 2 – GRANT AWARD

2.01 Grant: In accordance with the terms and conditions of this Agreement, including Section 5.07 – General Terms and Conditions, the Grantor shall provide the Grantee with a maximum of $10,000.00 (Grant Funds) to financially support and assist the Grantee’s implementation of Oil Spill Response Equipment Staging, Lake County (Project).

2.02 Term: The term of this Agreement is September 1, 2025, or upon the Grantor’s approval, whichever is later, through June 30, 2026.

SECTION 3 – ELIGIBLE USES OF GRANT
Only the Grantee expenditures that are necessary to implement this Project, comply with applicable federal and State of California law, and made in accordance with Section 6 – Project Statement and Section 9 – Budget and Payment as set forth within this Agreement are eligible for reimbursement from the Grant Funds.

SECTION 4 – GRANTEE’S REPRESENTATIONS AND WARRANTIES
The Grantee represents and warrants to the Grantor as follows:

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4.01 Existence and Power: The Grantee is a public entity, validly existing, and in good standing under the laws of California. The Grantee has full power and authority to transact the business in which it is engaged and full power, authority, and legal right to execute and deliver this Agreement and incur and perform its obligations hereunder.

4.02 Binding Obligation: This Agreement has been duly authorized, executed, and delivered on behalf of the Grantee and constitutes the legal, valid, and binding obligation of the Grantee, enforceable in accordance with this Agreement’s terms.

SECTION 5 – GRANTEE’S AGREEMENTS

5.01 Purpose: This Agreement is entered into by the Parties for the purpose of providing financial support to the Grantee to complete this Project, specifically the activities identified within Section 6 – Project Statement.

5.02 Project: The Grantee shall complete activities as set forth in Section 6 – Project Statement.

5.03 Use of Project Funds: The Grantee agrees that only Grantee expenditures that are necessary to implement this Project, comply with applicable federal and State of California law, and made in accordance with Section 6 – Project Statement and Section 9 – Budget and Payment as set forth within this Agreement are eligible for reimbursement from the Grant Funds. The Grantee acknowledges that it may not transfer Grant Funds between or among budget line items without written approval from the CDFW Grant Manager in accordance with Section 9 – Budget and Payment.

5.04 Payment Schedule: Payments shall be made to the Grantee according to the payment and report schedule identified in Section 9 – Budget and Payment.

5.05 Eligibility of Funds: In the event that the California Budget Act does not provide sufficient appropriations to allow the Grantor to fund this Project at the level specified in Section 2 – Grant Award and Section 9 – Budget and Payment of this Agreement, the Grantor reserves the right to modify this Agreement to reflect a reduction in available funds, as an alternative to termination.

5.06 Submission of Reports: The Grantee shall comply with the format, content, and timing requirements set out in Section 8 – Reports. Failure to submit timely and accurate reports shall be considered evidence of non-compliance with this Agreement and shall permit termination of this Agreement by the Grantor.

5.07 General Terms and Conditions: The Public Entities General Grant Provisions (Exhibit 1.a) and the Notice of Economic Sanctions (Exhibit 3) are attached hereto and made a part of this Agreement.

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5.08 Amendments: This Agreement may only be amended in accordance with Section

5.07 – General Terms and Conditions. The Grantee shall submit any request to amend any term of this Agreement in writing to the CDFW Grant Manager no later than 120 days prior to the end of the term of this Agreement. The Grantee must include an explanation of and justification for any such request.

5.09 Acknowledgement of Credit: The Grantee shall include signage, to the extent practicable, informing the public that this Project received funds through the CDFW. Further, the Grantee shall include appropriate acknowledgement of credit to the Office of Spill Prevention and Response (OSPR) Grant Program and its implementing agency, the CDFW, for the Grantor’s financial support when using any data and/or information developed under this Agreement (e.g., in posters, reports, publications, presentations).

5.10 Labor Code Requirements; Prevailing Wage: State grants may be subject to California Labor Code requirements, which include prevailing wage provisions.

Certain State grants administered by the CDFW are not subject to Chapter 1 (commencing with Section 1720) of Part 7 of Division 2 of the Labor Code. For more details, please refer to California Fish and Game Code Section 1501.5 and the Department of Industrial Relations website at http://www.dir.ca.gov. The Grantee shall pay the prevailing wage to all persons employed in the performance of any part of this Project if required by law to do so.

5.11 California Business and Professions Code Compliance: The Grantee shall be responsible for obtaining the services of an appropriately licensed professional or appropriately licensed professionals if required by the California Business and Professions Code, including but not limited to Section 6700 et seq. (Professional Engineers Act) and Section 7800 et seq. (Geologists and Geophysicists Act).

If the Grantee fails to perform in accordance with the compliance provisions of this Agreement, the Grantor shall have sole discretion to delay, interrupt, or suspend the work for which the Grant Funds are supplied.

SECTION 6 – PROJECT STATEMENT

6.01 Introduction: During an oil spill, California operates within the Incident Command System (ICS), a mechanism used to bring multiple jurisdictions under one standard operating arena. The ICS is managed by the Unified Command, and in most cases is comprised of a designated official from the United States Coast Guard, the OSPR, and the Responsible Party (Spiller); the three members make all decisions on how the oil spill incident operations are planned, executed, and demobilized.

Several Oil Spill Response Organizations (OSRO) are available to provide response and clean-up of oil spills throughout the State. However, in certain remote locations, the OSRO’s have difficulty or are unable to pre-stage response equipment. To address this problem, OSPR has established a grant program that Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 Q2575070

CITY OF LAKEPORT

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will provide local government agencies with funding to purchase spill response equipment, so they can initiate a first response prior to the OSRO’s arrival.

6.02 Objectives: The grant funding will enhance the availability of oil response equipment around the State and will provide local governments an opportunity to protect their economic resources. The Grantee will purchase the response equipment and provide training as identified in Oil Spill Response Equipment Staging, Lake County Equipment Specifications (Attachment I).

6.03 Project Description: The Grantee’s Project Manager (salary is not funded by this grant agreement) will be responsible for all aspects of the administration of this Grant which include procurement, training, staging, and usage of the equipment.

6.04 Location: The equipment will be staged at the City of Lakeport, located at 591 Martin St, Lakeport CA, 95453, Lake County.

6.05 Materials and Equipment: See Oil Spill Response Equipment Staging, Lake County, Equipment Specifications (Attachment I).

6.06 Project Implementation: Consistent with the Grantee’s proposal for this Project, the Grantee will complete the following tasks in accordance with Section 6.07 – Schedule of Due Dates and Deliverables:

Task 1 – Equipment Ordering
The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) will place an order per OSPR equipment specifications which is attached hereto as Oil Spill Response Equipment Staging, Lake County Equipment Specifications (Attachment I) and made a part of this Agreement. Items from Attachment I which will be purchased are Table 5; 400 ft of containment boom (4x6), Table 8; (2) Anchor systems, Table 11; (4) sets of PPE, Table 13; Heavy weight adsorbent pads, (2) bags of 100 pads Absorbent materials, Table 9; Watergate, Table 11; PFD’s.

Task 2 – Equipment Delivery & Familiarization/Training
The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) will coordinate the delivery of the equipment.

1. Ensure key response staff (actual staff and total number of staff, to be determined by the Grantee) receives training/familiarization which should entail:
a. Health and safety concerns when deploying the equipment on oil spills, b. Equipment familiarization,
c. Care, storage, and maintenance of the equipment,
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d. Usage as it pertains to the Local Geographic Response Plans and other pertinent strategies,
e. Decontamination of personnel and the equipment,
f. A practical hands-on deployment of the equipment, and g. Limitations of the equipment.

2. Submit a report to the CDFW Grant Manager with the equipment staging location.

3. The CDFW Grant Manager will perform an inspection of the equipment.

Task 3 – Project Management and Administration

1. The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) will furnish the necessary personnel, equipment, material and/or service(s) necessary for routine or incidental deployment of the equipment provided in this Agreement.

2. The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) may deploy the equipment in the event of an oil spill within the Grantee’s jurisdiction, for the shelf life of the equipment. The Grantee will notify the CDFW Grant Manager within 15 days, by phone or e-mail, when the equipment is used in conjunction with an oil spill response. The Grantee also agrees to notify the CDFW Grant Manager if the equipment is relocated to a different staging location within the jurisdiction.

3. The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) will provide the CDFW Grant Manager with equipment access such as facility/storage security access codes, keys to the gate and trailer locks, or designate staff to be on-site to allow the necessary access.

The Grantee’s Project Manager assisted by the Grantee’s Project Coordinator (salaries are not funded by this grant agreement) will be responsible for all aspects of the administration of this Agreement, including procurement, invoicing, final reporting, staging, and usage of the equipment.

6.07 Schedule of Due Dates and Deliverables:

Task Description Deliverables Estimated
Completion Dates
1 Equipment Ordering Equipment June 15, 2026
2 Equipment Delivery and
Inspection
Location Report &
Equipment Inspection
June 15, 2026
3 Project Management Invoice June 30, 2026
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SECTION 7 – CONTACTS
The point of contact may be changed at any time by either party by providing a 10 day advance written notice to the other party. The Parties hereby designate the following points of contact during the Term of this Agreement:

CDFW Grant Manager Grantee Project Manager
Name: Cindy Murphy Name: Kevin Ingram
Title: Staff Services Manager I
(Specialist)
Title: City Manager
Address: P.O. Box 944209
Sacramento, CA 94244-2090
Address: 225 Park Street
Lakeport, CA 95453
Phone: (916) 616-4515 Phone: (707) 263-5615
Email: [email protected] Email: [email protected] Direct all administrative inquiries to:

CDFW Grant Coordinator Grantee Project Coordinator
Name: Julia-Malia Olea Name: Jen Baker
Title: Contract/Grant Coordinator Title: Compliance Officer I Address: P.O. Box 944209
Sacramento, CA 94244-2090
Address: 591 Martin Street
Lakeport, CA 95453
Phone: (916) 216-1303 Phone: (707) 263-3578 ext 403
Email: [email protected] Email: [email protected] SECTION 8 – REPORTS

8.01 Final Report: No Progress Reports are required; however, the Grantee shall submit a Final Report by the date listed in Section 6.07 – Schedule of Due Dates and Deliverables. The report shall summarize the life of this Agreement and describe the work and results pursuant to Section 6 – Project Statement. The Final Report will be submitted, electronically, to the CDFW Grant Manager upon completion of the Project tasks. The CDFW Grant Manager will provide the Grantee a sample Final Report template, upon request. The Final Report will consist of one electronic version in Microsoft Word (or compatible format), upon the completion of this Project.

8.02 Document Accessibility: CDFW follows the Web accessibility standards of California Government Code Sections 7405 and 11135, and the Web Content Task Description Deliverables Estimated
Completion Dates
1 Equipment Ordering Equipment June 15, 2026
and Administration Final Report June 30, 2026
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Accessibility Guidelines (WCAG). Since all Office of Spill Prevention and Response Oil Spill Response Equipment Staging Final Reports will be posted to CDFW’s website, grantees must ensure that the WCAG standards for adequate accessibility to people with disabilities are met for all Reports and associated submittals. Final Reports, and all associated documents, should be submitted as Word Documents for ease of editing to meet WCAG standards.

SECTION 9 – BUDGET AND PAYMENT

9.01 Budget Details and Funding Summary: The Grantor will provide an amount not to exceed $10,000.00 as detailed below in the Line-Item Budget Detail (Budget) below. The Grantee or its partners will provide up to $0 in funds or in-kind services as cost share to complete tasks described in Section 6 – Project Statement. Actual expenditures will not be determined until the competitive process and equipment procurement has occurred. The procurement will consist of such items as a mobile storage trailer, boom, absorbents, anchors, personal protective equipment, equipment deployment training (if applicable) and all other items as outlined in Oil Spill Response Equipment Staging, Lake County Equipment Specifications (Attachment I).

Line-Item Budget Detail
A. PERSONNEL SERVICES
Not Applicable $0
Total Personnel Services $0
B. OPERATING EXPENSES: GENERAL
Equipment identified in Attachment I (Each item less than $5,000) $10,000.00 Subtotal Operating Expenses: General $10,000.00
C. OPERATING EXPENSES: SUBCONTRACTORS
Not Applicable $0
Subtotal Operating Expenses: Subcontractors $0
D. OPERATING EXPENSES: EQUIPMENT
Equipment identified in Attachment I ($5,000 or more per item) $0 Subtotal Operating Expenses: Equipment $0
E. INDIRECT COSTS
Indirect Charge Rate 0%
(Applies to Sections A + B only)
$0
F. GRAND TOTAL (A+B+C+D+E) $10,000.00

9.01.1 Budget Flexibility: The Grantee must submit all budget line item revision requests, in writing, to the CDFW Grant Manager, prior to implementing any changes. All proposed budget changes require prior approval from the CDFW Grant Manager, regardless of budgetary impact.

Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 Q2575070

CITY OF LAKEPORT

Page 8 of 10 ends

Informal Budget adjustments between existing line items may be permitted. Any revision to the Line-Item Budget Detail must comply with Section 5.08 – Amendments. Considerations for informal Budget adjustments, if granted, must include:

1. Revisions which are consistent with the purpose, objectives, and description of the Project as detailed in Section 6 – Project Statement;

2. Revisions that do not increase or decrease the total Agreement amount;

3. Revisions that do not substitute key personnel; and

4. Line-item shifts within a budget category (e.g., Field Supplies to Travel) up to $25,000 or 10% of the Agreement amount,
whichever is less.

Formal Budget adjustments will be considered by the Grantor, with prior approval from the CDFW Grant Manager. An amendment to the Agreement is required if a formal Budget adjustment is approved.

Considerations for formal amendments, if granted, include:

1. Shifting Grant Funds between budget categories (e.g., Personnel Services to Operating Expenses);

2. Increasing or decreasing the total Agreement amount;

3. Substituting key personnel; or

4. Line-item shifts within a budget category (e.g., Field Supplies to Travel) that exceeds $25,000 or 10% of the Agreement amount, whichever is less.

9.02 Payment Provisions:

9.02.1 Disbursements: Grant disbursements will be made to the Grantee in one lump sum payment in arrears, upon receipt of an original itemized invoice and any required mandatory documentation as identified in Section 6.07 – Schedule of Due Dates and Deliverables.

The Grant disbursements will be mailed to the following Grantee address:

Grantee Name: City of Lakeport
Attention: Jen Baker
Address: 225 Park Street
Lakeport, CA 95453

9.02.2 Invoice Documentation: The invoice for payment must be accompanied by the Final Report. If there is cost share involved with this project, the final invoice must include a budget summary of cost share expenditures by fund source. The CDFW Grant Manager will provide the Grantee with Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 Q2575070

CITY OF LAKEPORT

Page 9 of 10 ends

a sample invoice template upon request. The Final Invoice must be submitted to the CDFW Grant Manager by the date identified in Section

6.07 – Schedule of Due Dates and Deliverables. The invoice package must be sent hard copy or emailed to the CDFW Grant Manager, as identified in Section 7 – Contacts.

Requirements: The invoice shall contain the following information:

1. The word “Invoice” should appear in a prominent location at the top of the page(s);

2. The printed name of Grantee on company letterhead;

3. The Grantee’s business address, including P.O. Box, City, State, and Zip Code;

4. The name of the CDFW Region/Division being billed;

5. The invoice date and the time period covered; i.e., the term “from” and “to”;

6. This Agreement number and the sequential number of the invoice (i.e., Q2575070-Invoice 1);

7. The invoice must be itemized using the categories and following the format of the Budget;

8. The total amount due. This should be in a prominent location in the lower right-hand portion of the last page and clearly distinguished from other figures or computations appearing on the invoice. The total amount due shall include all costs incurred by the Grantee under the terms of this grant;

9. The original signature of the Grantee; and

10. The Grantee must provide supporting documentation for the invoice and actual receipts.

Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 Q2575070

CITY OF LAKEPORT

Page 10 of 10 ends

IN WITNESS WHEREOF, the parties hereto have caused this Agreement to be duly executed as of Grantor date set forth below the signature.

AUTHORIZED AGENT FOR GRANTEE
By:

Signature:

Printed Name:Kevin Ingram
Title: City Manager
Date:

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
By:

Signature:

Printed Name: Amy Mowrer
Title: Branch Manager, Business Management Branch
Date:

This Agreement is exempt from DGS-OLS approval, per SCM 4.06.

Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 9/4/2025
City of Lakeport
Agreement No. : Q2575070

Page 1 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I Table 1
Specifications for Equipment Trailer
Custom Built Approximate size of box 7’ x 16’ or 7’ x 12 Minimum ¼” plywood interior sidewall with finished surface Undercoated exterior grade ¾” plywood floor
Undercoating on complete chassis
Vapor barrier underbelly
16: o/c stud walls
24” o/c floor cross member frame
Fiberglass front cap
Aluminum roof and cove
Side vents (one on each side of trailer near top)
Aluminum fenders (thickness should be 3/16’)
Lighted license plate holder
Front stone guard
Electric brakes with breakaway switch and battery
GVRW 7000 lbs. (minimum)
Doors Double rear door with full length cam bar
Side door near front
Both doors fitted with pad lock securing mechanism
Electrical 12 volt dome lights with wall switch
7-way connector
D.O.T. compliant exterior lighting
Double insulated wiring
Suspension Tandem Axels
EZ lube hubs torsion axles
Tires 15” radial tires
5-bolt E-coated wheels
Wheel tire covers
½” wood tire parking pads
Wheel chocks
Spare tire and wheel with inside mount
Color White
“Oil Spill Response Equipment Funded by: Oil Spill Prevention and Response” stenciled in red 6” letters on 2 sides
2-digit trailer ID number stenciled on back of trailer in 6” black numbers 2-digit trailer ID number stenciled on top of trailer in 36” black numbers Tongue Hitch ball size 2 15/16”
Tongue jack with stand pad
D.O.T. safety chains
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 2 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I Warranty 3 Year Standard Manufactures Warranty
5 Year Axle Standard Manufacturers Warranty
20 Year Leak Manufactures Warranty
TABLE 2
Standard Oil Response Containment Boom Specifications
(various sizes available)
Freeboard 2.5”
Draft 4”
Overall Height 6.5”
Section Length 50’ 1,500ft
Fabric 22 oz./sq.yd PVC Coated Nylon Fabric
Color Yellow or International Orange
End Connectors ASTM “Z” (F 962-04) or ASTM Slide (F 2438-04) (style of connectors TBD)
With Stainless Steel Toggle Pins
Flotation 100 % Cylindrical Rolled Polyethylene micro or closed cell foam, with tapered ends
Fully sealed floatation cambers
Max. 14” fabric fold between flotation cambers
RF Welded Seams
Fold Point Center of fold points to be every 6 ½’
Anchor Points ¾” eye minimum, located at water line on each end connector & one at mid section, in a appropriate place of choosing
Ballast Material 1/4" Galvanized Chain
Bridle An ASTM End Plate with ½” x 6’ Poly Rope lead, one end to be finished with thimble connected to tow plate & 6” soft eye spliced into other end.

Warranty Standard Manufacturer’s Commercial Warranty
TABLE 3
Standard Storm Drain Containment Boom Specifications
Overall Height Bilge/Storm Drain Absorbent Boom 32" x 6" Section Length 20 per case
TABLE 4
Standard Sorbent Boom Specifications
Overall Height 6” – 8”
Section Length 120’ up to 720ft
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 3 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I TABLE 5
Standard Oil Response Containment Boom Specifications
Freeboard 4”
Draft 6”
Overall Height 10”
Section Length 100’ 1,000ft
Fabric 22 oz./sq.yd PVC Coated Nylon Fabric
Color Yellow or International Orange
End
Connectors
ASTM “Z” (F 962-04) or ASTM Slide (F 2438-04)
(style of connectors TBD)
With Stainless Steel Toggle Pins
Flotation 100 % Cylindrical Rolled Polyethylene micro or closed cell foam, with tapered ends
Fully sealed floatation cambers
Max. 14” fabric fold between flotation cambers
RF Welded Seams
Fold Point Center of fold points to be every 6 ½’
Anchor Points ¾” eye minimum, located at water line on each end connector & one at mid section, in a appropriate place of choosing
Ballast
Material
1/4" Galvanized Chain
Bridle An ASTM End Plate with ½” x 6’ Poly Rope lead, one end to be finished with thimble connected to tow plate & 6” soft eye spliced into other end.

Warranty Standard Manufacturer’s Commercial Warranty
TABLE 6
Standard Oil Response Containment Boom Specifications
Freeboard 6”
Draft 6”
Overall Height 12”
Section Length 100’ 1,000ft
Fabric 22 oz./sq.yd PVC Coated Nylon Fabric
Color Yellow or International Orange
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 4 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I End
Connectors
ASTM “Z” (F 962-04) or ASTM Slide (F 2438-04)
(style of connectors TBD)
With Stainless Steel Toggle Pins
Flotation 100 % Cylindrical Rolled Polyethylene micro or closed cell foam, with tapered ends
Fully sealed floatation cambers
Max. 14” fabric fold between flotation cambers
RF Welded Seams
Fold Point Center of fold points to be every 6 ½’
Anchor Points ¾” eye minimum, located at water line on each end connector & one at mid section, in a appropriate place of choosing
Ballast
Material
1/4" Galvanized Chain
Bridle An ASTM End Plate with ½” x 6’ Poly Rope lead, one end to be finished with thimble connected to tow plate & 6” soft eye spliced into other end.

Warranty Standard Manufacturer’s Commercial Warranty
TABLE 7
Standard Oil Response Containment Boom Specifications
Freeboard 6”
Draft 12”
Overall Height 18”
Section Length 100’ 1,000ft
Fabric 22 oz./sq.yd PVC Coated Nylon Fabric
Color Yellow or International Orange
End
Connectors
ASTM “Z” (F 962-04) or ASTM Slide (F 2438-04)
(style of connectors TBD)
With Stainless Steel Toggle Pins
Flotation 100 % Cylindrical Rolled Polyethylene micro or closed cell foam, with tapered ends
Fully sealed floatation cambers
Max. 14” fabric fold between flotation cambers
RF Welded Seams
Fold Point Center of fold points to be every 6 ½’
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 5 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I Anchor Points ¾” eye minimum, located at water line on each end connector & one at mid section, in a appropriate place of choosing
Ballast
Material
1/4" Galvanized Chain
Bridle An ASTM End Plate with ½” x 6’ Poly Rope lead, one end to be finished with thimble connected to tow plate & 6” soft eye spliced into other end.

Warranty Standard Manufacturer’s Commercial Warranty
TABLE 8
Anchor System Specifications
Anchor 30 lb. Danforth Style Galvanized Anchor
Chain 10 feet of 3/8” galvanized proof coil chain, shackled to anchor using ½” galvanized shackle
Rode 150 feet of ½” nylon 3-strand with galvanized thimble eyes and 7/16” SPA galvanized shackle in each end.

Flotation A2 Polyform style buoy (15.5”) with 6 feet of ½” polypropylene rope spliced onto buoy and ½” galvanized thimble eye in other end with 7/16” galvanized shackle.

Warranty Standard Manufacturer’s Commercial Warranty
TABLE 9
Water-Gate
Under Flow Various Sizes include: 21”H x 25’L, 28”H x 25’L, or 39”H x 30’L TABLE 10
Boom Tool Box Specifications
Tool Box 1 Heavy-duty poly toolbox. 24” length or larger if necessary to fit all tools Wrenches 2 8” crescent wrench
Pliers 1 8” standard pliers
Hammer 1 16 oz. claw hammer
Clamps 2 4” C-clamp
Screwdriver 2 Flathead screwdriver, small and large
Shackles 4 2 3/8” SPA galvanized shackles, 2 ½” SPA galvanized shackles Knife 1 Utility knife with extra blade set
Flashlight 1 Waterproof floatable flashlight with 2 D-cell batteries Hardware 6 Hardware set including: 5/16” x 1 ¼” SS bolts, 2 flat washers, nylock nuts
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 6 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I PVC 4 PVC pipe 6”x6’
Wire 1 50’ roll chicken wire or mesh fencing
Stakes 10 6’ t-post stakes and t-post pounder
Kit 1 Plug and Patch Kit
Hacksaw 1 12in. High Tension Hacksaw
Wire/Bolt
Cutters
1ea. 36’ Bolt Cutter
Generator 1 Gasoline Powered Electric Start Portable Generator with Wheel Kit Sand bags 30 14 x 26"
Shovel 2 Square Point Digging Shovels
TABLE 11
PPE Gear Specifications
Storage bag Reusable waterproof storage bag large enough to hold all 1 set of PPE Hard hat Hard hat with ratcheting head band
Boots 16” PVC steel toe work boots, size 11, ASTM F2413-05 M I/75 C/75 compliant
Glove liners Nitrile glove liners, 1 box of 100, large size Gloves PVC gloves, 1 dozen, 12” gauntlet, size 11 (large) Work gloves Leather work gloves, 2 pair, large size
Safety glasses 2 pair, meeting ANSI and OSHA specifications Ear plugs 6 pair
Tyvek suits Full tyvek suit without hood, 2 pair
Tape Duct tape, 2 rolls
PFD 4 pair. Onyx A/M-24 Automatic/ Manual Inflatable Life Jacket TABLE 12
Specifications for Decontamination Equipment
Wash Tubs 2 Galvanized wash tubs
Detergent Degreaser detergent for decontamination
Brushes 2 decontamination scrub brushes with long handles Waste Bags 1 case of 100 bags, 33” x 40”, 4 mil
Visqueen 1 roll of visqueen
Tarps 2 drop tarps, 8’ x 10’
Bucket 1 5-gallon plastic bucket
TABLE 13
Specifications for Spill Adsorbent Material
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 City of Lakeport
Agreement No. : Q2575070

Page 7 of 7 ends

Oil Spill Response Equipment Staging, Lake County Equipment Specifications Attachment I Pads Heavy weight adsorbent pads, 1 bag of 100 pads
Sweep 100 feet of 19” heavy weight sweep with nylon web strap, bonded with scrim
Boom 1 bag of heavy weight boom containing 4 sections of 5” x 10’ each with poly tension line and quick-clips for connecting
TABLE 14
Specifications for Spill Adsorbent Material
Snare Adsorbent snares, 2 bags, 30 snares per bag
TABLE 15
Miscellaneous Equipment Specifications
First Aid Kit Meeting the requirements for at least 10 people Fire
Extinguishers
2 5-pound class ABC fire extinguishers, mounted in trailer interior, one near the front and one near the rear.

MSDS Book A binder containing MSDS for common oil products including gasoline, diesel, home heating oil, motor oil, jet fuel, fuel oil, IFO, bunker fuel, and crude oil.

Also contains emergency contact numbers for spill, including the National Response Center (1-800-424-8802)
Navigation
Lights
Self-floating amber buoy lights 48” tall to attach on or near boom. Lights should be made durable and waterproof, and should have adequate keel weight and floatation to give full stability in various tide and sea conditions. Lights should be flashing; D-cell battery operated, and be fitted with photo sensors.

Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 State of California - Natural Resources Agency GAVIN NEWSOM, Governor DEPARTMENT OF FISH AND WILDLIFE CHARLTON H. BONHAM, Director P.O. Box 944209
Sacramento, CA 94244-2090
www.wildlife.ca.gov
Conserving California’s Wildlife Since 1870
September 4, 2025
Kevin Ingram
City of Lakeport
25 Park Street
Lakeport, CA 95453
Re: Q2575070 – Oil Spill Response Equipment Staging, Lake County

ACKNOWLEDGEMENT OF WORK COMMENCEMENT AUTHORIZATION DISCLAIMER Where approval from the California Department of Fish and Wildlife (CDFW) applies, the attached payable grant shall be of no force or effect until it is signed by both parties (CDFW and grantee). The signing of this payable grant by your organization does not authorize the commencement of work.

By signing this letter, your organization acknowledges and agrees not to begin work until all approvals have been obtained, the payable grant has been fully executed, and the grantee has been given authorization to begin work. Should any work begin before all approvals are obtained or authorization is given, services will be considered voluntary.

Please be advised that failure to sign and return this letter will delay approval of your payable grant.
_______________________________________ _______________________ Authorized Signature Date
Kevin Ingram, City Manager
Printed Name and Title of Person Signing
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112 9/4/2025

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 1 of 7 ends

(Rev. 07/08/2021)

1. APPROVAL: This Agreement is of no force or effect until signed by both Parties. Grantee shall not incur any costs in reliance on this Agreement until this Agreement has been signed by both Parties.

2. AMENDMENT: No amendment or variation of the terms of this Agreement shall be valid unless made in writing and signed by the Parties. Only persons duly authorized to sign an amendment on behalf of CDFW may do so. No oral understanding or agreement not incorporated in this Agreement is binding on either of the Parties.

3. ASSIGNMENT: This Agreement is not assignable by Grantee, either in whole or in part, without written approval from CDFW.

4. AUDIT: Grantee agrees that CDFW, the Department of Finance (“DOF”), Department of General Services (“DGS”), California State Auditor’s Office (“CSA”), or their designated representatives shall have the right to review and to copy any records and supporting documentation related to the performance of this Agreement. Grantee agrees to maintain such records for possible audit for a minimum of three years after CDFW’s final payment to Grantee pursuant to this Agreement, unless a longer period of records retention is stipulated. Grantee agrees to allow the auditor(s) access to such records during normal business hours and to allow interviews of any employees who might reasonably have information related to such records.

Further, Grantee agrees to include the following term or a substantially similar term in any subcontract related to performance of this Agreement:

Subcontractor agrees that CDFW, the Department of Finance, Department of General Services, California State Auditor’s Office, or their designated representatives shall have the right to review and to copy any records and supporting documentation related to the performance of this agreement. Subcontractor agrees to maintain such records for possible audit for a minimum of three years after final payment, unless a longer period of records retention is stipulated.

Subcontractor agrees to allow the auditor(s) access to such records during normal business hours and to allow interviews of any employees who might reasonably have information related to such records. Subcontractor agrees to put a substantially similar term in any subcontract it executes with another entity related to the performance of this agreement.

5. INDEMNIFICATION: Grantee agrees to indemnify, defend, and save harmless the State of California (“State”) and CDFW and their officers, agents, and employees from any and all claims and losses accruing or resulting to any and all subcontractors, suppliers, laborers, and any other person, firm, or corporation furnishing or supplying work services, materials, or supplies in connection with the performance of this Agreement, and from any and all claims and losses accruing or resulting to any person, firm, or corporation who may be injured or damaged by Grantee in the performance of this Agreement.

CDFW agrees to indemnify, defend, and save harmless Grantee and its officers, agents, and employees from any and all claims and losses accruing or resulting to any and all subcontractors, Q2575070
City of Lakeport
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 2 of 7 ends

(Rev. 07/08/2021)
suppliers, laborers, and any other person, firm, or corporation furnishing or supplying work services, materials, or supplies in connection with the performance of this Agreement, and from any and all claims and losses accruing or resulting to any person, firm, or corporation who may be injured or damaged by CDFW in the performance of this Agreement but, collectively, only in proportion to and to the extent that such claims or losses are caused by or result from the negligent or intentional acts or omissions of CDFW or its officers, agents, and employees.

6. DISPUTES: Grantee shall continue with its responsibilities under this Agreement during any dispute.

7. INDEPENDENT CONTRACTOR: Grantee, and the agents and employees of Grantee, in the performance of this Agreement, shall act in an independent capacity and not as officers or employees or agents of CDFW. Grantee acknowledges and promises that CDFW is not acting as an employer to any individuals furnishing services or work on the Project pursuant to this Agreement.

8. NON-DISCRIMINATION CLAUSE: During the performance of this Agreement, Grantee shall not unlawfully discriminate against, harass, or allow harassment against any employee or applicant for employment because of race, religion, color, national origin, ancestry, physical disability (including HIV and AIDS), mental disability, medical condition, marital status, age (over 40), sex, sexual orientation, or use of family-care leave, medical-care leave, or pregnancy-disability leave.

Grantee shall take affirmative action to ensure that the evaluation and treatment of its employees and applicants for employment are free of such discrimination and harassment. Such action shall include, but not be limited to, the following: employment, upgrading, demotion or transfer; recruitment or recruitment advertising; layoff or termination; rates of pay or other forms of compensation; and selection for training, including apprenticeship. Grantee shall comply with the provisions of the Fair Employment and Housing Act (Government Code, Section 12900 (a-f) et seq.) and applicable regulations (California Code of Regulations, Title 2, Section 7285 et seq.).

The regulations of the Fair Employment and Housing Commission regarding Contractor Nondiscrimination and Compliance (Chapter 5 of Division 4 of Title 2 of the California Code of Regulations) are incorporated by reference into this Agreement. Grantee shall give written notice of its obligations under this non-discrimination clause to labor organizations with which Grantee has a collective bargaining or other agreement and shall post in conspicuous places available to employees and applicants for employment notice setting forth the provisions of this Section 8. Further, Grantee agrees to include the following term or a substantially similar term in any subcontract related to performance of this Agreement:

During the performance of this agreement, Subcontractor shall not unlawfully discriminate against, harass, or allow harassment against any employee or applicant for employment because of race, religion, color, national origin, ancestry, physical disability (including HIV and AIDS), mental disability, medical condition, marital status, age (over 40), sex, sexual orientation, or use of familycare leave, medical-care leave, or pregnancy-disability leave. Subcontractor shall take affirmative action to ensure that the evaluation and treatment of its employees and applicants for employment Q2575070
City of Lakeport
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 3 of 7 ends

(Rev. 07/08/2021)
are free of such discrimination and harassment. Such action shall include, but not be limited to, the following: employment, upgrading, demotion or transfer; recruitment or recruitment advertising; layoff or termination; rates of pay or other forms of compensation; and selection for training, including apprenticeship. Subcontractor shall comply with the provisions of the Fair Employment and Housing Act (Government Code, Section 12900 (a-f) et seq.) and applicable regulations (California Code of Regulations, Title 2, Section 7285 et seq.). The regulations of the Fair Employment and Housing Commission regarding Contractor Nondiscrimination and Compliance (Chapter 5 of Division 4 of Title 2 of the California Code of Regulations) are incorporated by reference into this agreement. Subcontractor shall give written notice of its obligations under this non-discrimination clause to labor organizations with which Subcontractor has a collective bargaining or other agreement and shall post in conspicuous places available to employees and applicants for employment notice setting forth the provisions of this section.

Subcontractor agrees to put a substantially similar term in any subcontract it executes with another entity related to the performance of this agreement.

9. UNENFORCEABLE PROVISION: In the event that any provision of this Agreement is unenforceable or held to be unenforceable, then the Parties agree that all other provisions of this Agreement have force and effect and shall not be affected thereby.

10. REGULATORY COMPLIANCE: Grantee’s implementation of the Project must comply with all applicable federal, state, and local government statutes, laws, regulations, codes, ordinances, orders, or other governmental and quasi-governmental requirements that apply to the Project (including its planning, construction, management, monitoring, operation, use, and maintenance).

The costs associated with such regulatory compliance may be reimbursed under this Agreement only to the extent authorized by the Budget Detail and Funding Summary section of this Agreement.

Grantee’s implementation of the Project must comply with the California Labor Code. Projects funded in whole or in part with CDFW grant funds may be public works projects under the Labor Code. (See Section 1720 et seq.) Labor Code compliance may require the payment of prevailing wage. Grantee is responsible for Labor Code compliance, and CDFW cannot provide advice about Labor Code compliance.

Grantee’s implementation of the Project must comply with the California Business and Professions Code. Grantee shall be responsible for obtaining the services of an appropriately licensed professional if required by the Business and Professions Code, including but not limited to Section 6700 et seq. (Professional Engineers Act) and Section 7800 et seq. (Geologists and Geophysicists Act). CDFW cannot provide advice about Business and Professions Code compliance.

11. RIGHTS IN DATA: Grantee agrees that all data, plans, drawings, specifications, reports, computer programs, operating manuals, notes, and other written or graphic work produced in the performance of this Agreement, are subject to the rights of CDFW as set forth in this Section 11.

CDFW shall have the right to reproduce, publish, and use all such work, or any part thereof, in any manner and for any purposes whatsoever and to authorize others to do so. If any such work Q2575070
City of Lakeport
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 4 of 7 ends

(Rev. 07/08/2021)
is copyrightable, Grantee may copyright the same, except that, as to any work which is copyrighted by Grantee, CDFW reserves a royalty-free, nonexclusive and irrevocable license to reproduce, publish, and use such work, or any part thereof, and to authorize others to do so.

12. CONTINGENT FUNDING: It is mutually understood between the Parties that this Agreement may have been written before ascertaining the availability of State appropriation of funds for the mutual benefit of both Parties in order to avoid program and fiscal delays which would occur if this Agreement were executed after that determination was made.

This Agreement is valid and enforceable only if sufficient funds are made available pursuant to the California State Budget Act for the fiscal year(s) covered by this Agreement for the purposes of this program. In addition, this Agreement is subject to any additional restrictions, limitations, or conditions enacted by the State Legislature of any statute enacted by the Legislature which may affect the provisions, terms, or funding of this Agreement in any manner.

If the Legislature does not appropriate sufficient funds for this Agreement, CDFW may terminate this Agreement in accordance with Section 13 of this Exhibit 1.a or amend this Agreement to reflect any reduction of funds.

13. RIGHT TO TERMINATE:
a. This agreement may be terminated by mutual consent of both Parties or by any Party upon 30 days written notice and delivered in person, USPS First Class Mail, or electronic transmission.
b. In the event of termination of this Agreement, Grantee shall immediately provide CDFW an accounting of all Grant Funds received under this Agreement. c. Any such termination of this Agreement shall be without prejudice to any obligations or liabilities of either Party already incurred prior to such termination. CDFW shall reimburse Grantee for all allowable and reasonable costs incurred by Grantee for the Project, including foreseeable and uncancellable obligations. Upon notification of termination from CDFW, Grantee shall make reasonable efforts to limit any outstanding financial commitments.

14. USE OF SUBCONTRACTOR(S): If Grantee desires to accomplish part of the Project through the use of one or more subcontractors, the following conditions must be met:
a. Grantee shall submit any subcontracts to CDFW for inclusion in the grant file; b. Agreements between the Grantee and the subcontractor must be in writing; c. Subcontracts must include language establishing the audit rights of CDFW, DOF, DGS, CSA, or their designated representatives with respect to subcontractors that complies with Section 4 of this Exhibit 1.a.;
d. Subcontracts must include non-discrimination clause language with respect to subcontractors that complies with Section 8 of this Exhibit 1.a; and e. Upon termination of any subcontract, the CDFW Grant Manager shall be notified immediately, in writing.

Q2575070
City of Lakeport
Docusign Envelope ID: 5FB3B59C-5BF7-4CCA-BC3F-0D359D843112

CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 5 of 7 ends

(Rev. 07/08/2021)

15. POTENTIAL SUBCONTRACTOR(S): Nothing contained in this Agreement or otherwise shall create any contractual relation between CDFW and any of Grantee’s subcontractor(s) and no subcontract shall relieve Grantee of its responsibilities and obligations hereunder. Grantee agrees to be as fully responsible to CDFW for the acts and omissions of its subcontractor(s) and of persons directly employed or indirectly employed by any of them as it is for the acts and omissions of persons directly employed by Grantee. Grantee’s obligation to pay its subcontractor(s) is an independent obligation from CDFW’s obligation to make payments to Grantee. As a result, CDFW shall have no obligation to pay or to enforce the payment of any monies to any of Grantee’s subcontractors.

16. TRAVEL AND PER DIEM: If the reimbursement of travel or per diem costs are authorized by this Agreement, such costs shall be reasonable and not exceed those amounts identified in the California Department of Human Resources travel reimbursement guidelines. No travel outside the State of California shall be reimbursed unless prior written authorization is obtained from the CDFW Grant Manager.

17. LIABILITY INSURANCE : Unless otherwise specified in this Agreement, when Grantee submits a signed Agreement to CDFW, Grantee shall also furnish to CDFW either proof of self-insurance or a certificate of insurance stating that there is liability insurance presently in effect for Grantee of not less than $1,000,000 per occurrence for bodily injury and property damage liability combined. Grantee agrees to make the entire insurance policy available to CDFW upon request.

The certificate of insurance will include provisions a, b, and c, in their entirety:
a. The insurer will not cancel the insured’s coverage without 30-days prior written notice to CDFW;
b. The State and CDFW and their officers, agents, employees, and servants are included as additional insured, insofar as the operations under this Agreement are concerned; and c. CDFW will not be responsible for any premiums or assessments on the policy.

Grantee agrees that the liability insurance herein provided for, shall be in effect at all times during the term of this Agreement. In the event said insurance coverage expires at any time or times during the term of this Agreement, Grantee agrees to provide, prior to said expiration date, a new certificate of insurance evidencing insurance coverage as provided for herein for not less than the remainder of the term of this Agreement, or for a period of not less than one year. New certificates of insurance are subject to the approval of CDFW, and Grantee agrees that no work or services shall be performed prior to CDFW giving such approval. In the event Grantee fails to keep in effect, at all times, insurance coverage as herein provided, CDFW may, in addition to any other remedies it may have, terminate this Agreement upon occurrence of such event.

CDFW will not provide for, nor compensate Grantee for any insurance premiums or costs for any type or amount of insurance. The insurance required above, shall cover all Grantee supplied personnel and equipment used in the performance of this Agreement. If subcontractors performing work for Grantee under this Agreement cannot provide to Grantee either proof of self-insurance Q2575070
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CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 6 of 7 ends

(Rev. 07/08/2021)
or a certificate of insurance stating that the subcontractor has liability insurance of not less than $1,000,000 per occurrence for bodily injury or property damage liability combined, then Grantee’s liability insurance shall provide such coverage for the subcontractor.

18. GRANTEE STAFF REQUIREMENTS: Grantee represents that it has or shall secure at its own expense, all staff required to perform the services described in this Agreement. Such personnel shall not be employees of or have any contractual relationship with CDFW.

19. EQUIPMENT PURCHASES: For purposes of this Agreement, “Equipment” means tangible personal property having a useful life of four years, and “Major Equipment” means Equipment with a unit cost of $5,000 or more. The unit cost includes the purchase price plus all costs to acquire, install, and prepare the equipment for its intended use. Grantee may purchase Major Equipment under this Agreement only when a specific type Major Equipment is listed in the Budget Details and Funding Summary section of this Agreement. This restriction on the purchase of Major Equipment does not include the lease or rental of Major Equipment. Grantee shall own all Equipment purchased under this Agreement; CDFW does not claim title or ownership to such Equipment. Grantee shall keep, and make available to CDFW upon CDFW’s request, appropriate records of all Equipment purchased with Grant Funds. Equipment purchased by Grantee outside the term of this Agreement is not eligible for reimbursement by CDFW under this Agreement.

When Grantee submits an invoice to CDFW for reimbursement of Major Equipment purchase costs, that invoice must include a receipt listing the purchase price of the Major Equipment and the serial number and model number of the Major Equipment. That invoice must also include the location, including street address, where the Major Equipment will be used during the term of this Agreement.

20. GRANTEE’S PROCUREMENT OF GOODS AND/OR SERVICES: Grantee’s process for procuring goods or services to carry out the Project under this Agreement must reasonably ensure that Grantee is making sound business decisions.

21. DRUG-FREE WORKPLACE CERTIFICATION: Grantee will comply with the requirements of the Drug-Free Workplace Act of 1990 (Government Code, Section 8350 et seq.) and will provide a drug-free workplace by taking the following actions:
a. Publish a statement notifying employees that unlawful manufacture, distribution, dispensation, possession, or use of a controlled substance is prohibited and specifying actions to be taken against employees for violations.
b. Establish a Drug-Free Awareness Program to inform employees about all of the following:

1. the dangers of drug abuse in the workplace;

2. the person's or organization's policy of maintaining a drug-free workplace;

3. any available counseling, rehabilitation, and employee assistance programs; and,

4. penalties that may be imposed upon employees for drug abuse violations. c. Every employee who works on the proposed Agreement will:

1. receive a copy of the company's drug-free policy statement; and Q2575070
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CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 1a – PUBLIC ENTITIES GENERAL GRANT PROVISIONS
Grant Agreement Number:

Grantee Name:

Page 7 of 7 ends

(Rev. 07/08/2021)

2. agree to abide by the terms of the company's statement as a condition of employment on the Agreement.

Failure to comply with these requirements may result in suspension of disbursements under this Agreement or termination of the Agreement or both, and Grantee may be ineligible for award of any future State agreements if CDFW determines that any of the following has occurred: (1) Grantee has made false certification or (2) Grantee has violated the certification by failing to carry out the requirements as noted above.

22. UNION ORGANIZING: Grantee acknowledges the applicability to this Agreement of Government Code Sections 16645 through 16649, and certifies that:
a. No Grant Funds disbursed pursuant to this Agreement will be used to assist, promote, or deter union organizing;
b. Grantee shall account for Grant Funds disbursed for a specific expenditure pursuant to this Agreement to show those funds were allocated to that expenditure; c. Grantee shall, where Grant Funds are not designated as described in Section 22(b) above, allocate, on a pro-rata basis, all disbursements that support the grant program; and d. If Grantee makes expenditures to assist, promote, or deter union organizing, Grantee will maintain records sufficient to show that no Grant Funds were used for those expenditures and shall provide those records to the Attorney General upon request.

23. GOVERNING LAW: This Agreement is governed by and shall be interpreted in accordance with the laws of the State of California.

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CALIFORNIA DEPARTMENT OF FISH AND WILDLIFE
EXHIBIT 3 – NOTICE OF ECONOMIC SANCTIONS
Grant Agreement Number:

Grantee Name:

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(Rev. 06/24/2022)
Grantee and its subcontractor(s), collectively referred to as “Grantee”, shall follow Federal, State, and local orders, guidelines and directives, and CDFW policies related to any Executive Order (EO) issued by the Governor of the State of California regarding economic sanctions.

Executive Order N-6-22 – Russia Sanctions
On March 4, 2022, Governor Gavin Newsom issued Executive Order N-6-22 (the EO) regarding Economic Sanctions against Russia and Russian entities and individuals. “Economic Sanctions” refers to sanctions imposed by the U.S. government in response to Russia’s actions in Ukraine, as well as any sanctions imposed under state law. The EO directs state agencies to terminate grants with, and to refrain from entering any new grants with, individuals or entities that are determined to be a target of Economic Sanctions. Accordingly, should the State determine Grantee is a target of Economic Sanctions or is conducting prohibited transactions with sanctioned individuals or entities, that shall be grounds for termination of this agreement. The State shall provide Grantee advance written notice of such termination, allowing Grantee at least 30 calendar days to provide a written response. Termination shall be at the sole discretion of the State.

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Meeting Date: 10/21/2025 Page 1 Agenda Item #VI.A

CITY OF LAKEPORT
City Council ☒
City of Lakeport Municipal Sewer District ☐
Lakeport Industrial Development Authority ☐
Municipal Financing Agency of Lakeport ☐

STAFF REPORT
RE: Discussion and Consideration of the City of Lakeport Joining Sonoma Clean Power
MEETING DATE: 10/21/2025
SUBMITTED BY: Kevin M. Ingram, City Manager
PURPOSE OF REPORT: ☐Information only ☒ Discussion ☒Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

Receive a presentation from Sonoma Clean Power (SCP) staff and consider adoption of:

1. A Resolution requesting the Sonoma Clean Power Authority act as Community Choice Aggregator (CCA) for the City of Lakeport; and

2. An Ordinance authorizing the implementation of a CCA program within the City and participation in SCP’s Joint Power Authority.

BACKGROUND:

Sonoma Clean Power (SCP) is a Community Choice Aggregation (CCA) program — a public, not-for-profit agency that purchases electricity generation on behalf of customers in Sonoma and Mendocino Counties, while Pacific Gas and Electric (PG&E) continues to own, maintain, and operate the poles, wires, and substations of the power grid. There are currently 25 operational CCA programs in California, serving more than 14 million customers statewide.

The Lake County Board of Supervisors unanimously passed Ordinance 3206 on June 23, 2015, authorizing the implementation of a CCA program with the goal of reducing energy costs for local residents and businesses. At that time, however, SCP was not in a position to expand services to include Lake County. Lake County reevaluated CCA participation in 2019, when it requested SCP to conduct a feasibility study on expanding service to the County. SCP’s study, released in March 2020, concluded that it was unable to offer competitive service to Lake County customers due to the expected cost of PG&E’s Power Charge Indifference Adjustment (PCIA) fee for Lake County compared to SCP’s existing customer base. The PCIA is a state-mandated fee designed to ensure that customers leaving investor-owned utilities, such as PG&E, do not shift prior power procurement costs onto remaining ratepayers.

Since that time, market and regulatory conditions have improved significantly. SCP re-engaged with the Board of Supervisors in April 2025, and staff from all three Lake County jurisdictions expressed interest in exploring the potential benefits of joining SCP. Subsequently, in May 2025, SCP completed an updated Feasibility Study for Lake County, which found that expansion could result in average customer bill savings between 4.2% and 12.9% under typical market conditions, and confirmed that SCP’s existing renewable energy portfolio could accommodate Lake County without the need for new long-term power procurement.

SCP followed its feasibility study with presentations to each of the three local jurisdictions and several community advisory groups throughout the County. On June 17, 2025, SCP staff presented the updated Meeting Date: 10/21/2025 Page 2 Agenda Item #VI.A
feasibility findings to the Lakeport City Council. The presentation reviewed SCP’s mission, rate competitiveness, customer advocacy services, and potential community benefits, and the Council directed staff to continue evaluating the opportunity and participating in regional discussions.

In August 2025, SCP’s Board of Directors formally authorized the expansion of service to Lake County and voted to offer one (1) Board seat for the County of Lake and one (1) shared seat for the Cities of Lakeport and Clearlake. Actions by the three Lake County jurisdictions to join SCP must be completed by the end of October 2025 in order to allow SCP adequate time to amend its Implementation Plan, add Lake County, and file the revised plan with the California Public Utilities Commission (CPUC)—authorizing a start of service in May 2027.

Despite formal service not beginning until 2027, the SCP Board has agreed to allow appointment of the two Lake County Board representatives (one appointed by the Board of Supervisors and one jointly representing the cities) beginning in January 2026.

The City Council joined the County of Lake and the City of Clearlake in a Joint Workshop on September 30, 2025, to further explore the option of public power generation through SCP. The workshop reviewed SCP’s operations, governance, rate-setting structure, and next steps toward potential service expansion, and provided an opportunity for both the public and elected officials to engage directly with SCP staff regarding program benefits and implications. No formal action was taken at that meeting.

Following the workshop, SCP issued a letter on October 2, 2025 (Attachment 5) addressing areas of concern raised during the discussion. The letter reiterated SCP’s commitment to proactive consultation with Lake County’s Tribal Governments prior to the start of service in 2027, and clarified misunderstandings about SCP’s Geothermal Opportunity Zone (GeoZone) initiative. The GeoZone is an exploratory framework for identifying and developing geothermal resources through a transparent public process; SCP confirmed that no specific projects are currently proposed in Lake County and that any future proposals would include robust opportunities for public input and local review as part of both the GeoZone planning process and subsequent project approvals.

On October 2, 2025, the City of Clearlake considered a formal resolution to join SCP. Following an additional presentation from SCP staff, public comment, and Council deliberation, the Clearlake City Council voted 3–2 not to join SCP or extend CCA service to the City of Clearlake. The Council cited concerns about the timing of the decision and a lack of community support for the GeoZone initiative as the primary reasons for declining to participate. SCP later issued a clarifying letter to the Clearlake City Council (Attachment 5), which was also shared with the Lake County Board of Supervisors and the Lakeport City Council, further explaining the purpose of the GeoZone and emphasizing local participation, community protections, and the continued land use authority of local jurisdictions.

Following Clearlake’s action, City of Lakeport staff conferred with SCP staff regarding the implications of moving forward with only Lakeport and the unincorporated County as participants. Although SCP’s initial expansion offer contemplated participation from all three Lake County jurisdictions, SCP staff confirmed that they would recommend to their Board to continue offering service to the City of Lakeport and the unincorporated County if strong support remains from the elected officials of both jurisdictions.

The Lake County Board of Supervisors is scheduled to consider its own resolution and ordinance to join SCP at its regular meeting on the morning of October 21, 2025, prior to the City Council’s consideration of the matter later that evening.

DISCUSSION:

Staff Recommendation: City staff recommends that the City Council adopt the attached resolution and ordinance authorizing the City of Lakeport to join Sonoma Clean Power (SCP) and participate in its Community Choice Aggregation (CCA) program.

The 2025 Lake County Feasibility Study demonstrates that joining SCP is financially viable and presents favorable conditions for reduced overall electricity costs for Lake County residents and businesses when compared to Pacific Gas & Electric (PG&E). While future rate reductions cannot be guaranteed due to market and regulatory Meeting Date: 10/21/2025 Page 3 Agenda Item #VI.A
variability, SCP’s established record of competitive rates and rate stability suggests a strong likelihood of customer savings over time.

Beyond potential cost savings, City staff views the customer advocacy and service component of SCP as a significant public benefit. SCP provides direct support to residents and local businesses struggling with high and fluctuating electric bills, offering personalized assistance to navigate complex rate structures and identify the most cost-effective plans for their specific needs. This service—often lacking under traditional investor-owned utility models—represents a substantial value to the Lakeport community and aligns with the City’s ongoing efforts to support local economic resilience.

City staff also acknowledges community concerns related to future geothermal development in the region.

However, these concerns often stem from misunderstandings about SCP’s Geothermal Opportunity Zone (GeoZone) initiative. Rather than promoting unchecked development, the GeoZone framework would provide Lake County and its local governments with a stronger leadership role and policy voice in how geothermal projects are planned, reviewed, and implemented. Participation in SCP in no way alters or diminishes the City’s or County’s existing land use authority over future geothermal projects. In fact, membership in SCP ensures that Lake County jurisdictions have a seat at the table in shaping both local and state-level policy around clean energy and geothermal resources.

In conclusion, City staff believes that joining Sonoma Clean Power offers Lakeport a meaningful opportunity to enhance local control, improve rate transparency, strengthen energy advocacy for residents and businesses, and reinforce the region’s role in shaping equitable, community-driven clean energy policy. For these reasons, staff recommends that the City Council adopt the presented resolution and ordinance authorizing the City’s participation in Sonoma Clean Power.

Why Both a Resolution and Ordinance are Required: Under California Public Utilities Code Section 366.2 (Assembly Bill 117), local jurisdictions must take two formal steps to join a Community Choice Aggregation program:

1. Resolution: Formally requesting that the Sonoma Clean Power Authority act as the Community Choice Aggregator on the City’s behalf; and

2. Ordinance: Authorizing implementation of a Community Choice Aggregation program within the City’s jurisdiction.

Together, these actions fulfill the statutory requirements for program participation and enrollment in the SCP Joint Powers Authority (JPA). The City’s adoption of both documents is necessary to effectuate membership and enable SCP to file required documentation with the California Public Utilities Commission (CPUC).

Overview of Attachments: Several attachments are provided as a part of this staff report providing background on the City’s consideration of joining Sonoma Clean Power (SCP), including the required authorizing documents, implementation plan, feasibility analysis, and supplemental correspondence from SCP and community representatives.
• Attachment 1 – Resolution Requesting SCP Service: Formally requests that Sonoma Clean Power act as the City’s Community Choice Aggregator and implement the program within Lakeport. • Attachment 2 – Ordinance Authorizing Implementation of a CCA Program: Authorizes the City’s participation in the SCP Joint Powers Authority and delegates authority to the City Manager to execute related documents.
• Attachment 3 – Sonoma Clean Power Second Revised and Updated Implementation Plan (with JPA Document): Outlines SCP’s operational framework, compliance with state law, and governance structure. The Joint Powers Agreement (JPA) establishing SCP is included as an appendix. • Attachment 4 – 2025 Lake County Expansion Feasibility Study: Provides the technical and economic analysis supporting SCP’s expansion to Lake County. Includes rate impact modeling, startup costs, and risk evaluation.

Meeting Date: 10/21/2025 Page 4 Agenda Item #VI.A
• Attachment 5 – Correspondence and Supplemental Information: Consists of clarification materials from Sonoma Clean Power regarding its offer of service and the GeoZone initiative, as well as correspondence received from community representatives expressing perspectives and insights related to the proposed Lake County expansion.

OPTIONS:

1. Adopt the Resolution and introduce the Ordinance authorizing participation in Sonoma Clean Power.

2. Deny the request to join Sonoma Clean Power and direct staff to notify SCP and the County of Lake that the City will not be participating in the Community Choice Aggregation program at this time.

3. Take no action.

4. Or alternatively, the Council may provide staff alternative direction.

FISCAL IMPACT:
☒ None ☐ $ Budgeted Item? ☐Yes ☒ No
Budget Adjustment Needed? ☐Yes ☒ No If yes, amount of appropriation increase: $ Affected fund(s): ☐ General Fund ☐ Water OM Fund ☐ Sewer OM Fund ☐ Other:

Comments: There is no direct fiscal impact to the City’s General Fund associated with joining Sonoma Clean Power (SCP). Startup and operational costs are funded through program revenues, with SCP assuming full responsibility for expenses related to electricity generation service.

However, it should be noted that future action to withdraw from the program could involve administrative and transition costs, such as customer notification requirements, potential settlement of shared financial obligations under the Joint Powers Agreement, and other expenses associated with returning local customers to PG&E service. These risks are considered minimal under current SCP policy; however, the potential costs and complexities could increase if withdrawal were to occur after service implementation and customer enrollment.

COUNCIL PRIORITIES:
☐ Priority #1: Public Safety & Crisis Response
☐ Priority #2: Disaster Resiliency
☒ Priority #3: Good Governance & Fiscal Stability
☐ Priority #4: Capital Infrastructure Improvement
☐ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Motion to Adopt the Resolution
Move to adopt the resolution requesting that the Sonoma Clean Power Authority act as the Community Choice Aggregator for the City of Lakeport and authorize the implementation of Sonoma Clean Power’s Community Choice Aggregation Program within the City limits.

Motion to Introduce the Ordinance
Meeting Date: 10/21/2025 Page 5 Agenda Item #VI.A
Move to introduce and waive the first reading of the ordinance authorizing the implementation of a Community Choice Aggregation Program within the City of Lakeport and approving the City’s participation in the Sonoma Clean Power Joint Powers Authority.
☒ Attachments: 1. Resolution Requesting Sonoma Clean Power Act as Community Choice Aggregator for the City of Lakeport

2. Ordinance Authorizing the Implementation of a Community Choice Aggregation Program by Participating with the Sonoma Clean Power Authority

3. Sonoma Clean Power Implementation Plan

4. Sonoma Clean Power Feasibility Study for Expansion of Service to Lake County (May 2025)

5. Received Comments & Correspondence
ATTACHMENT 1
Resolution Requesting SCP Service
RESOLUTION NO. ______

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF LAKEPORT

REQUESTING THAT THE SONOMA CLEAN POWER AUTHORITY

ACT AS COMMUNITY CHOICE AGGREGATOR ON BEHALF OF THE

CITY AND IMPLEMENT THE SONOMA CLEAN POWER COMMUNITY

CHOICE AGGREGATION PROGRAM WITHIN THE CITY
WHEREAS, the City of Lakeport (“City") has been actively investigating options to provide electric services to constituents within its service area with the intent of achieving greater local involvement over the provision of electric services and promoting competitive and renewable energy; and
WHEREAS, on September 24, 2002, the Governor signed into law Assembly Bill 117 (Stat. 2002, Ch. 838; see California Public Utilities Code section 366.2; hereinafter referred to as the "Act"), which authorizes any California city or county, whose governing body so elects, to combine the electricity load of its residents and businesses in a community-wide electricity aggregation program known as Community Choice Aggregation ("CCA"); and
WHEREAS, the Act expressly authorizes participation in a CCA program through a joint powers agency, and on December 4, 2012, the Sonoma Clean Power Authority ("SCPA") was established as a joint powers authority pursuant to a Joint Powers Agreement, as amended from time to time ("SCPA Joint Powers Agreement"); and WHEREAS, in October of 2013, the California Public Utilities Commission certified the "Implementation Plan" for SCPA's CCA program, approved a First Revised and Updated Implementation Plan in February 2015, and approved a Second Revised and Updated Implementation Plan in December 2016, confirming SCPA's compliance with the requirements of the Act; and
WHEREAS, the City Council of the City of Lakeport is concurrently adopting an ordinance determining that implementation of a CCA program is in the public interest and welfare of its residents, and elected to authorize and implement a CCA program within the City; and
WHEREAS, the City Council supports the goals stated in the SCPA Joint Powers Agreement, which are to address climate change by reducing greenhouse gas emissions, to provide electric power at a competitive cost, to carry out programs to reduce energy use, to provide for long-term electric rate stability and energy security and reliability for residents through local control of electric generation resources, and to stimulate and sustain the local economy; and
WHEREAS, the City Council supports SCPA's current electricity procurement plan, which increases the amount of renewable energy available to customers and reduces greenhouse gas emissions; and
WHEREAS, SCPA representatives have stated a willingness to consider including one Lake County representative on the SCPA Board and a second Lake County representative (collectively representing the cities) if all eligible Lake County cities apply and are accepted for participation in the SCPA; and
WHEREAS, SCPA representatives have stated a willingness to consider proportional and equitable use of program funds and mutually beneficial local partnerships; and
WHEREAS, in order to participate in SCPA's CCA program, the Act requires the City to individually adopt a resolution requesting that SCPA act as the community choice aggregator on behalf of the City; and
WHEREAS, the City Council wishes to make such a request, so that SCPA can provide CCA service to the City.

NOW, THEREFORE, BE IT RESOLVED by the City Council of the City of Lakeport as follows:

1. The foregoing recitals are true and correct.

2. Based upon all of the above, the City Council requests that the Sonoma Clean Power Authority act as Community Choice Aggregator on its behalf within the jurisdiction of the City, and authorizes the Authority to implement and carry out within the City the community choice aggregation program as generally described in the Second Revised and Updated Implementation Plan. The City Council further wishes to become a participant in SCPA’s CCA Program.

3. The City Clerk is hereby directed to forward a copy of this resolution to the Sonoma Clean Power Authority.

4. The City Manager is authorized to sign other documents as needed to implement this process.

5. The adoption of this Resolution is not a project under the California Environmental Quality Act ("CEQA") because it does not involve any commitment to a specific project which may result in a potentially significant physical impact on the environment, as contemplated by Title 14, California Code of Regulations, Section 15378 ("State CEQA Guidelines"), therefore, the adoption of this Resolution is not subject to CEQA pursuant to State CEQA Guidelines Sections 15060(c) and 15061(b)(3).

6. This Resolution shall be effective upon its adoption.

The foregoing Resolution was adopted at a regular meeting of the City Council of the City of Lakeport held on the 21st of October, 2025, by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:
_____________________________
Kim Costa, Mayor
ATTEST:
______________________________
Kelly Buendia, City Clerk
ATTACHMENT 2
Ordinance Authorizing Implementation of a
CCA Program
ORDINANCE NO. ______

AN ORDINANCE OF THE CITY COUNCIL OF THE CITY OF LAKEPORT

AUTHORIZING THE IMPLEMENTATION OF A COMMUNITY CHOICE

AGGREGATION PROGRAM BY PARTICIPATING WITH THE SONOMA

CLEAN POWER AUTHORITY
The City Council of the City of Lakeport hereby ordains as follows:

SECTION 1. The City Council of the City of Lakeport has been actively investigating options to provide electric services to constituents within its service area with the intent of achieving greater local involvement over the provision of electric services and promoting competitive and renewable energy.

SECTION 2. On September 24, 2002, the Governor signed into law Assembly Bill 117 (Stat. 2002, Ch. 838; see California Public Utilities Code section 366.2; hereinafter referred to as the "Act"), which authorizes any California city or county, whose governing body so elects, to combine the electricity load of its residents and businesses in a community-wide electricity aggregation program known as Community Choice Aggregation ("CCA").

SECTION 3. The Act expressly authorizes participation in a CCA program through a joint powers agency, and on December 4, 2012, the Sonoma Clean Power Authority ("SCPA") was established as a joint powers authority pursuant to a Joint Powers Agreement, as amended from time to time ("SCPA Joint Powers Agreement").

SECTION 4. in October of 2013, the California Public Utilities Commission certified the "Implementation Plan" for SCPA's CCA program, approved a First Revised and Updated Implementation Plan in February 2015, and approved a Second Revised and Updated Implementation Plan in December 2016, confirming SCPA's compliance with the requirements of the Act.

SECTION 5. On July 15, 2025 and September 30, 2025, the City Council of the City of Lakeport heard presentations and received public comment regarding SCPA's CCA program. In order to participate in SCPA's CCA program, the Act requires the City to adopt an ordinance electing to implement SCPA's CCA program in its jurisdiction. All public notices regarding consideration of this Ordinance were provided.

SECTION 6. Based upon all of the above, the City Council of the City of Lakeport elects to implement a Community Choice Aggregation program within the City, through the City's participation as a "Participant" in the SCPA CCA program as defined in the SCPA Joint Powers Agreement. The City Manager is hereby authorized to execute any documents necessary for the City's participation in the program.

SECTION 7. The passage of this Ordinance is not a project under the California Environmental Quality Act (CEQA) because it does not involve any commitment to a specific project which may result in a potentially significant physical impact on the environment, as contemplated by Title 14, California Code of Regulations, Sections 15378 ("CEQA Regulations"), and is therefore not subject to CEQA pursuant to CEQA Guidelines Sections 15060 and 15061(b)(3).

SECTION 8. If any section, subsection, sentence, clause, phrase or word of this Ordinance is for any reason held to be invalid by a court of competent jurisdiction, such decision shall not affect the validity of the remaining portions of this Ordinance. The City Council of the City of Lakeport hereby declares it would have passed and adopted this Ordinance and each and all provisions hereof irrespective of the fact that any one or more of said provisions be declared invalid.

SECTION 9. This Ordinance shall be and the same is hereby declared to be in full force and effect from and after thirty (30) days after the date of its passage. The City Clerk shall publish the Ordinance or cause a summary of said Ordinance to be published as provided by law.

The foregoing Ordinance was introduced at a regular meeting of the City Council of the City of Lakeport held on October 21, 2025, and adopted at a regular meeting of the City Council of the City of Lakeport held on ________________, by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:
_____________________________
Kim Costa, Mayor
ATTEST:
______________________________
Kelly Buendia, City Clerk
ATTACHMENT 3
Sonoma Clean Power Second Revised and
Updated Implementation Plan
Sonoma Clean Power Community Choice
Aggregation Implementation Plan and
Statement of Intent
(Second Revised and Updated)
October 2016
This update to the Sonoma Clean Power CCA Implementation Plan and Statement of Intent makes the following changes to January 2015 version:

1. Adds the County of Mendocino and the cities of Fort Bragg, Point Arena and Willits to the geographic service territory;

2. Updates load forecasts and financials to account for additional customers in the new territory;

3. Makes minor updates the plan to reflect the current SCP program organizational structure, finances and planning.
i January 2015
Table of Contents
Table of Contents ...........................................................................................i CHAPTER 1 – Introduction ..............................................................................2 CHAPTER 2 – Aggregation Process ...................................................................6 CHAPTER 3 – Organizational Structure ...........................................................10 CHAPTER 4 – Financial Plan for Expansion to New Cities ...................................15 CHAPTER 5 – Customer Enrollment Phasing ....................................................17 CHAPTER 6 - Load Forecast and Resource Plan ................................................18 CHAPTER 7 – Financial Plan for Ongoing Program Operation ..............................31 CHAPTER 8 - Ratesetting and Program Terms and Conditions ............................34 CHAPTER 9 – Customer Rights and Responsibilities ..........................................39 CHAPTER 10 - Procurement Process ...............................................................42 CHAPTER 11 – Contingency Plan for Program Termination.................................44 CHAPTER 12 – Appendices ............................................................................45 Appendix A: SCPA Board Certification of this Plan ..........................................46 Appendix B: SCP New Member Ordinances....................................................47 Appendix C: Sonoma Clean Power Joint Powers Agreement............................87 2 October 2016
CHAPTER 1 – Introduction
The Sonoma Clean Power Authority (“SCPA”) is a public agency located in Sonoma and Mendocino Counties, formed for the purposes of implementing a community choice aggregation (“CCA”) program (“SCP” or the “SCP Program”). Member Agencies of SCP include the County of Sonoma and the Sonoma County Water Agency (“Members” or “Member Agencies”). The County of Mendocino and the municipalities of Cloverdale, Cotati, Fort Bragg, Petaluma, Point Arena, Rohnert Park, Santa Rosa, Sebastopol, Sonoma, Willits and Windsor (“Participants” or “Participating Cities”) have elected to participate on the governing board and allow SCP to provide service within their jurisdictions. This Implementation Plan and Statement of Intent (“Implementation Plan”) describes SCP’s plans to expand the implementation of a voluntary CCA program for electric customers within the jurisdictional boundaries of its Member Agencies and Participating Cities that currently take bundled electric service from Pacific Gas and Electric Company (“PG&E”). The SCP Program gives electricity customers the opportunity to join together to procure electricity from competitive suppliers, with such electricity being delivered over PG&E’s transmission and distribution system. SCP first started serving customers on May 1, 2014 and the planned start date for the County of Mendocino and the cities of Fort Bragg, Point Arena and Willits is June 1, 2017. All current PG&E customers within the new SCP service area will receive information describing the SCP Program and will have multiple opportunities to express their desire to remain full requirement customers of PG&E, in which case they will not be enrolled. Thus, participation in the SCP Program is completely voluntary; however, customers, as provided by law, will be automatically enrolled unless they affirmatively elect to opt out.

SCP's CCA program enables customers within SCP’s service area to take advantage of the opportunities granted by Assembly Bill 117 (“AB 117”), the Community Choice Aggregation Law. SCP’s primary objectives in implementing this Program are to provide cost competitive electric services; stimulate and sustain the local economy by developing local jobs in renewable energy and energy efficiency; reduce greenhouse gas emissions related to use of power in Sonoma and Mendocino Counties; implement energy efficiency and demand reduction programs; and develop long-term rate stability and energy reliability for residents through local control. The prospective benefits to consumers include a substantial decrease in greenhouse gas emissions, stable and competitive electric rates, public participation in determining which technologies are utilized to meet local electricity needs, and local/regional economic benefits.
3 October 2016
To ensure continuing successful operation of the Program, SCP has hired industry experts in the roles of CEO, Director of Power Services, General Counsel and Regulatory Affairs Manager. Information regarding SCP’s procurement process is provided in the program’s Resource Plan, available at:
sonomacleanpower.org/scp-resource-plan
In addition, SCP is subject to the requirements of SB 350, and will be preparing an Integrated Resource Plan, which will be provided to the CPUC on the Commission’s schedule in 2017.

SCP’s Implementation Plan reflects a collaborative effort among SCP, its Members and Participants, and the private sector to bring the benefits of competition and choice to electric customers in Sonoma County. By exercising its legal right to form a CCA Program, SCP enables its Members’ and Participants’ constituents to access the competitive market for energy services and obtain access to increased renewable energy supplies and reductions in GHG emissions. Absent action by SCP and its individual Members and Participants, most customers would have no ability to choose an electric supplier and would remain captive customers of the incumbent utility.

The California Public Utilities Code provides the relevant legal authority for SCP to become a Community Choice Aggregator and invests the California Public Utilities Commission (“CPUC” or “Commission”) with the responsibility for establishing the cost recovery mechanism that must be in place before customers can begin receiving electrical service through the SCP Program. The CPUC also has responsibility for registering SCP as a Community Choice Aggregator and ensuring compliance with basic consumer protection rules. The Public Utilities Code requires that an Implementation Plan be adopted at a duly noticed public hearing and that it be filed with the Commission in order for the Commission to determine the cost recovery mechanism to be paid by customers of the Program in order to prevent shifting of costs to bundled customers of the incumbent utility.

On August 15, 2013, at a duly noticed public hearing, pursuant to SCP Resolution No. 2013-0005 (a copy of which is included as a part of Appendix A), SCP considered and adopted the original version of this Implementation Plan. On October 4, 2013 the Commission certified the original version of this Implementation Plan. On January 17, 2014 SCP finalized registration as a CCA with the Commission. The SCPA Board of Directors voted unanimously to approve and adopt a revised and updated version of the Implementation Plan at a duly noticed public hearing held on January 8, 2015. And this current version was approved by the SCPA Board of Directors on October 13, 2016 by Resolution No. 2016-005 (also included in Appendix A.
4 October 2016
For SCP customers receiving service under prior versions of this Implementation Plan, the Commission established the methodology for determining the cost recovery mechanism, and PG&E approved tariffs for the imposition of the cost recovery mechanism. SCP’s newly participating jurisdictions – the County of Mendocino and Cities of Fort Bragg, Point Arena and Willits – have each adopted a resolution and ordinance permitting SCP to provide service within their jurisdictions.
1 To move forward with providing service to the newly participating jurisdictions, SCP now submits this revised and updated Implementation Plan to the CPUC. Following the CPUC’s certification of its receipt of this revised and updated Implementation Plan and resolution of any outstanding issues, SCP will begin the customer notification and enrollment process for customers in the newly participating jurisdictions.

Organization of this Implementation Plan
The content of this Implementation Plan complies with the statutory requirements of AB 117. As required by PU Code Section 366.2(c)(3), this Implementation Plan details the process and consequences of aggregation and provides SCP’s statement of intent for implementing a CCA program that includes all of the following:

Ø Universal access;
Ø Reliability;
Ø Equitable treatment of all customer classes; and
Ø Any requirements established by state law or by the CPUC concerning aggregated service.

The remainder of this Implementation Plan is organized as follows:

Chapter 2: Aggregation Process
Chapter 3: Organizational Structure
Chapter 4: Financial Plan for Expansion to New Cities
Chapter 5: Customer Enrollment Phasing
Chapter 6: Load Forecast and Resource Plan
Chapter 7: Financial Plan for Ongoing Program Operation Chapter 8: Ratesetting and Program Terms and Conditions Chapter 9: Customer Rights and Responsibilities
Chapter 10: Procurement Process
Chapter 11: Contingency Plan for Program Termination
Appendix A: SCP Resolutions Approving Implementation Plans and Member and Participant Ordinances
Appendix B: Joint Powers Agreement

1 Copies of individual ordinances adopted by SCP’s Members and individual resolutions and ordinances adopted by SCP Participants are included as Appendix A. 5 October 2016
The requirements of AB 117 are cross-referenced to Chapters of this Implementation Plan in the following table.

AB 117 Cross References
AB 117 REQUIREMENT IMPLEMENTATION PLAN

CHAPTER
Statement of Intent Chapter 1: Introduction
Process and consequences of
aggregation
Chapter 2: Aggregation Process
Organizational structure of the
program, its operations and funding
Chapter 3: Organizational Structure
Chapter 4: Financial Plan for
Expansion to New Cities
Chapter 7: Financial Plan for
Ongoing Program Operation
Ratesetting and other costs to
participants
Chapter 8: Ratesetting and Program
Terms and Conditions
Chapter 9: Customer Rights and
Responsibilities
Disclosure and due process in setting
rates and allocating costs among
participants
Chapter 8: Ratesetting and Program
Terms and Conditions
Methods for entering and terminating
agreements with other entities
Chapter 10: Procurement Process
Participant rights and responsibilities Chapter 5: Customer Enrollment Phasing
Chapter 9: Customer Rights and
Responsibilities
Termination of the program Chapter 11: Contingency Plan for Program Termination
Description of third parties that will
be supplying electricity under the
program, including information about
financial, technical and operational
capabilities
Chapter 3: Organizational Structure
Chapter 10: Procurement Process
6 October 2016
CHAPTER 2 – Aggregation Process
Introduction
This chapter describes the background leading to the development of this Implementation Plan and describes the process and consequences of aggregation, consistent with the requirements of AB 117.

Beginning in 2010, the Sonoma County Water Agency, the County of Sonoma (“County”) and Sonoma County municipalities began investigating formation of a CCA Program, pursuant to California state law, with the following primary objectives: 1) provide cost competitive electric services; 2) stimulate and sustain the local economy by developing local jobs in renewable energy; 3) reduce greenhouse gas emissions related to use of power in Sonoma County; and 4) develop long-term rate stability and energy reliability for residents through local control. A feasibility study for a CCA Program serving the region and an independent review of the study were both completed in October 2011.

After nearly a year of collaborative work by representatives of the participating municipalities, independent consultants, local experts and stakeholders, the participating municipalities released a draft Implementation Plan in October 2012, which described the planned organization, governance and operation of the CCA Program. Consistent with the Implementation Plan’s described organizational structure, SCP was formed on December 4, 2012 to implement the SCP Program.

The original SCP Implementation Plan was submitted to the CPUC on August 20, 2013 and certified by the CPUC on October 4, 2013.

The SCP Program represents a culmination of planning efforts that are responsive to the expressed needs and priorities of the citizenry and business community within its territory. SCP has expanded the energy choices available to eligible customers through its default service called “CleanStart,” improved net metering program, feed-in tariff and 100 percent local and renewable program called “EverGreen.” Also, SCP is actively developing additional program activity in the areas of electric vehicles and related infrastructure, demand response tools and load aggregation, energy efficiency, and possibly customized pricing options for large energy users.

Process of Aggregation
Before customers of newly participating jurisdictions are enrolled in the Program, they receive two written notices in the mail, from SCP, that provide the information needed to understand the Program’s terms and conditions of service and explain how customers can opt out of the Program, if desired. All customers that do not follow the opt-out process specified in the customer notices will be automatically enrolled, and service will begin at their next regularly scheduled meter read date at 7 October 2016
least thirty days following the date of automatic enrollment, subject to the service phase-in plan described in Chapter 5. The initial enrollment notices will be provided to the next phase of new customers in March 2017. Initial enrollment notices will be provided to subsequent customer phases consistent with statutory requirements.

Customers enrolled in the SCP Program will continue to have their electric meters read and to be billed for electric service by the distribution utility (PG&E). The electric bill for Program customers shows separate charges for generation procured by SCP as well as other charges related to electricity delivery and other utility charges assessed by PG&E.

After service cutover, customers will have approximately 60 days (two billing cycles) to opt out of the SCP Program without penalty and return to the distribution utility (PG&E). SCP customers will be advised of these opportunities via the distribution of two additional enrollment notices provided within the first two months of service. Customers that opt out between the initial cutover date and the close of the post enrollment opt-out period will be responsible for program charges for the time they were served by SCP but will not otherwise be subject to any penalty for leaving the program. Customers that have not opted-out within thirty days of the fourth enrollment notice will be deemed to have elected to become a participant in the SCP Program and to have agreed to the SCP Program’s terms and conditions, including those pertaining to requests for termination of service, as further described in Chapter 8.

Consequences of Aggregation
Rate Impacts
SCP Customers will pay the generation charges set by SCP and no longer pay the costs of PG&E generation. Customers enrolled in the Program will be subject to the Program’s terms and conditions, including responsibility for payment of all Program charges as described in Chapter 9.

SCP’s rate setting policies described in Chapter 7 establish a goal of providing rates that are competitive with the projected generation rates offered by the incumbent distribution utility (PG&E). SCP’s governing board, with input from SCP’s Customer Advisory Committee, sets rates sufficient to recover the costs related to operation of the Program.

SCP’s current rates are between 1% and 5% lower than PG&E’s rates, current as of September 1, 2016, when all electric charges and fees are compared. Information regarding prevailing SCP Program rates will be disclosed along with other terms and conditions of service in the enrollment notices sent to potential customers. 8 October 2016
Once SCP gives definitive notice to PG&E that it will commence service to customers in the newly participating jurisdictions, SCP customers will generally not be responsible for costs associated with PG&E’s future electricity procurement contracts or power plant investments. Certain pre-existing generation costs and new generation costs that are deemed to provide system-wide benefits, and which CCAs do not elect to self-procure, will continue to be charged by PG&E to CCA customers through separate rate components, called the Cost Responsibility Surcharge and the New System Generation Charge. These charges are shown in PG&E’s electric service tariffs, which can be accessed from the utility’s website, and the costs are included in charges paid by both PG&E bundled customers as well as CCA and Direct Access customers.
2 Lower Greenhouse Gas Impacts
A second consequence of the Program is an increase in the proportion of energy generated and supplied by qualifying renewable and hydroelectric resources. SCP's resource plan includes procurement of diverse sources of renewable energy sufficient to meet a minimum of 40 percent of the SCP Program’s electricity needs for all enrolled customers and greenhouse gas (GHG) emissions that are at least 20 percent lower than PG&E’s emissions. SCP’s 2015 GHG emissions are forecast to be 45% lower than PG&E’s 2015 GHG emissions, but this is still subject to review and third-party verification.

SCP customers may also voluntarily participate in a 100 percent local and renewable supply option called EverGreen. To the extent that customers choose SCP’s 100 percent renewable energy option, the renewable content of SCP’s power supply will be even greater and the GHG emissions even lower. This renewable energy is currently met with baseload geothermal energy, but is expected to be met by a 50/50 mix of solar photovoltaic and geothermal by the end of 2017. SCP emphasizes procurement from local renewable energy projects to the greatest extent practical.

Energy Efficiency Impacts
A third consequence of the Program will be an increase in energy efficiency program investments and activities. The existing energy efficiency programs administered by the distribution utility have not changed, and are not expected to change, as a result of SCP’s operation. CCA customers will continue to pay the public benefits surcharges to the distribution utility which will fund energy efficiency programs for all customers, regardless of generation supplier. The energy efficiency

2 For PG&E bundled service customers, the Power Charge Indifference Adjustment element of the Cost Responsibility Surcharge is contained within the tariffed Generation rate. Other elements of the Cost Responsibility Surcharge are set forth in PG&E’s tariffs as separate rate charges paid by all customers (with limited exceptions).
9 October 2016
investments ultimately planned for the SCP Program, as described in Chapter 5, will be in addition to the level of investment that would continue in the absence of the SCP Program. Thus, the SCP Program has the potential for increased energy savings and a further reduction in emissions due to expanded energy efficiency programs. SCP may apply for administration of requisite program funding from the CPUC to independently administer energy efficiency programs within its jurisdiction. 10 October 2016
CHAPTER 3 – Organizational Structure
This section provides an overview of the organizational structure of SCP and its implementation of the CCA program. Specifically, the key agreements, governance, management, and organizational functions of SCP are outlined and discussed below.

Organizational Overview
The SCP Program has a governing board that establishes SCP Program policies and objectives; staff management that is responsible for operating the SCP Program in accordance with such policies, and contractors that provide energy and other specialized services necessary for SCP Program operations.

Governance
The SCP Program is governed by the Sonoma Clean Power Authority’s (SCPA) Joint Powers Agreement (JPA). Pursuant to the terms of the JPA, each participating jurisdiction appoints up to one member to serve on SCPA's Board of Directors (“Board”). In the case of the incorporated cities of Mendocino County, one Director represents all three cities. The SCPA Board is comprised of representatives appointed by the municipalities of Cloverdale, Cotati, Petaluma, Rohnert Park, Santa Rosa, Sebastopol, Sonoma, Windsor, the County of Sonoma (which also represents the Sonoma County Water Agency), the County of Mendocino, and one Director jointly representing the cities of Fort Bragg, Point Arena and Willits. The SCP Program is operated under the direction of a Chief Executive Officer appointed by the Board, with legal and regulatory services provided by a Board-appointed General Counsel.

The Board’s primary duties are to establish program policies, approve budgets and rates and provide policy direction to the Chief Executive Officer, who has general responsibility for program operations. The Board selects a Chair and other officers from among its membership and may establish an Executive Committee and other committees and sub-committees as needed. The SCPA Board also has established a Community Advisory Committee to provide additional public review of major activities including programs, budgets and rates.

Management
The Chief Executive Officer is an employee of SCP, and the Board is responsible for evaluating and managing the Chief Executive Officer’s performance.

The Chief Executive Officer has management responsibilities over the functional areas of Resource Planning, Electric Supply, Local Energy Programs, Finance and 11 October 2016
Rates, Customer Services and Regulatory Affairs. In performing his or her obligations to SCP, the Chief Executive Officer utilizes a combination of internal staff and contractors. Certain specialized functions needed for program operations, namely scheduling and customer account management functions, are currently performed by experienced third-party contractors.

Major SCP functions that are managed by the Chief Executive Officer are summarized below.

Resource Planning
SCP must plan for meeting the electricity needs of its customers utilizing resources consistent with its policy goals and objectives. The Chief Executive Officer oversees SCP’s Director of Power Services, and Director of Programs who develop SCP’s Integrated Resource Plan under the policy guidance provided by the Board and in compliance with California Law and other requirements of California regulatory bodies.

Long-term resource planning includes load forecasting and supply planning on a ten- to twenty-year time horizon. SCP currently has a mid-term five year Resource Plan, and is in the process of developing its first long-term resource plan as part of the SB350 IRP process. SCP resource planning will focus on lowering greenhouse gas emissions and limiting customer costs through demand-side load management and efficiency, distributed generation and demand response programs in addition to traditional supply options, which rely on structured wholesale transactions to meet customer energy requirements. SCP’s Integrated Resource Plan will be updated and adopted by the Board on an annual basis.

Electric Supply Operations
Electric supply operations encompass the activities necessary for wholesale procurement of electricity to serve end-use customers. These highly specialized activities include the following:

Ø Load Forecasting – develop accurate load forecasts, both long-term for resource planning and short-term for the electricity purchases and sales needed to maintain a balance between hourly resources and loads.

Ø Electricity Procurement – assemble a diverse portfolio of electricity resources to supply the electric needs of Program customers.

Ø Risk Management – application of standard industry techniques to reduce exposure to the volatility of energy markets and insulate customer rates from sudden changes in wholesale market prices.

Ø Scheduling Coordination – scheduling and settling electric supply transactions with the California Independent System Operator (CAISO). 12 October 2016
SCP manages these activities primarily with staff, and contracts for scheduling coordination with a third party.

Local Energy Programs
A key focus of the SCP Program is the development and implementation of local energy programs, including load management and efficiency programs, distributed generation programs and other energy programs responsive to community needs.

SCP’s Director of Programs, under direction from the Chief Executive Officer, is responsible for further development of these programs.

SCP will administer an increasing mix of greenhouse gas reduction, energy efficiency, demand response and distributed generation programs that can be used as cost-effective alternatives to procurement of supply-side resources while supporting the local economy. SCP may attempt to consolidate existing demandside programs into this organization and will expand energy efficiency offerings to customers throughout its service territory. SCP may apply for CPUC third-party administration of energy programs and use of funds collected through the existing public benefits surcharges paid by SCP customers.

To date, SCP has launched the following Local Energy Programs:
• Contracted for 15.5 MW of new local solar;
• Created a preferred net metering program to expand customer installations of renewable energy;
• Created a broad electric vehicle program that includes test drive events, educational material, negotiated discounts for vehicles, coordination of EV charging infrastructure installation between agencies, a bid into PG&E’s 2017 DRAM for aggregated load management with EV charging systems, and Switch Vehicle Lab funding for four schools; • Established a hotline for help with how to evaluate bids and hire solar installers; • Developed a demand response app for residential and small commercial customers; Additional programs are in development.

Finance and Rates
The Chief Executive Officer is responsible for managing the financial affairs of SCP, including the development of an annual budget, revenue requirement and rates; managing and maintaining cash flow requirements; arranging potential bridge loans as necessary and other financial tools.

The Board of Directors has the ultimate responsibility for approving the electric generation rates for SCP’s customers. The Chief Executive Officer, in coordination with staff and advisors, consultants and committees of the Board will be responsible for developing proposed rates and options for the Board to consider before 13 October 2016
finalization. The final approved rates will general be set to meet the annual budgetary revenue requirement developed by the Chief Executive Officer, including recovery of all expenses and any reserves or coverage requirements set forth in bond covenants or other agreements. In limited circumstances, the Board may choose to adopt rates that utilize reserve funds to offset costs. The Board has the flexibility to consider rate adjustments subject to its adopted policies, provided that the overall revenue requirement is achieved. SCP will administer a standardized set of electric rates and may offer optional rates to encourage policy goals such as economic development or low-income subsidy programs.

SCP may also offer customized pricing options such as dynamic pricing or contractbased pricing for energy intensive customers to help these customers gain greater control over their energy costs. This would provide such customers – mostly large business users – with a greater range of power options than currently available to them.

SCP’s finance function is responsible for arranging financing necessary for power purchase, any capital projects, preparing financial reports, and ensuring sufficient cash flow for successful operation of the SCP Program. The finance function plays an important role in risk management by monitoring the credit of energy suppliers so that credit risk is properly understood and mitigated. In the event that changes in a supplier’s financial condition and/or credit rating are identified, SCP will be able to take appropriate action, as is provided for in the electric supply agreement(s).

The Finance function establishes general credit policies that the SCP Program must follow.

Communications and Customer Services
The customer services function includes general program marketing and communications under SCP’s Director of Marketing and Public Affairs, as well as direct customer interface ranging from management of key account relationships to call center and billing operations under SCP’s Customer Care Manager and Account Executive. SCP conducts program marketing to raise consumer awareness of SCP and to establish the SCP “brand” in the minds of the public, with the goal of retaining and attracting as many customers as possible into the SCP Program.

Communications are sometimes directed at key policy-makers at the state and local level, community business and opinion leaders, and the media.

In addition to general program communications and marketing, a significant focus on customer service, particularly representation for key accounts, enhances SCP’s ability to differentiate itself as a highly customer-focused organization that is responsive to the needs of the community. SCP contracts with a customer call center designed to field customer inquiries and routine interaction with customer accounts, and SCP also has once customer service call center representative in house as part of its staff.
14 October 2016
The customer service function encompasses management of customer data.

Customer data management services include retail settlements/billing-related activities and management of a customer database. This function processes customer service requests and administers customer enrollments and departures from the SCP Program, maintaining a current database of enrolled customers. This function coordinates the issuance of monthly bills through the distribution utility’s billing process and tracks customer payments. Activities include the electronic exchange of usage, billing, and payment data with the distribution utility and SCP, tracking of customer payments and accounts receivable, and issuance of late payment and/or service termination notices (which would return affected customers to bundled service).

The customer data management services function also manages billing-related communications with customers and routine customer notices. SCP has contracted with a third party, who has demonstrated the necessary experience and administers appropriate computer systems (customer information system), to perform the customer account and billing services functions, but SCP has also begun to bring significant services in-house, including some call center representatives and billing analytics.

Legal and Regulatory Representation
The SCP Program requires ongoing regulatory management of compliance filings related to resource plans, resource adequacy, compliance with California’s Renewables Portfolio Standard (“RPS”), and overall representation on issues that will impact SCP, its Members, Participants and customers. SCP’s General Counsel and SCP’s Regulatory Affairs Manager provide these services, and are supported by the three staff in the Power Services department and outside counsel.

SCP’s legal and regulatory staff also provide important oversight to the distribution utilities fees on SCP’s customers. There is currently no outside organization tasked with ensuring PG&E does not shift costs from bundled customers onto SCP’s customers, so this important oversight function currently rests on SCP’s staff and consultants.

SCP's General Counsel provides all legal services to SCP, retaining outside counsel as needed.
15 October 2016
CHAPTER 4 – Financial Plan for Expansion to New Cities
This Chapter presents SCP’s financial plans for the expansion of service to the new territory in Mendocino County. Current program financial performance is strong, with SCP’s net position over $40 million after 26 months of operations. Throughout that time, SCP’s customers have collectively saved over $62 million on their total electric charges, according to data provided by PG&E on their rate comparisons.

Startup Activities
SCP has adequate cash on hand to enter into new contracts for energy and resource adequacy needed to serve Mendocino County.

Over the past two years, SCP has completed the following startup activities for its existing service territory, and now continues to build on this work to serve the new territory in Mendocino County:

Ø Hired staff and contractors to manage implementation
Ø Negotiated supplier contracts
• Electric supply
• Meter Data Management and Billing
• Will now negotiate for energy and resource adequacy for new load Ø Defined and executed communications plan
• Customer research/information gathering
• Media campaign
• Key customer/stakeholder outreach
• Informational materials and customer notices
• Customer call center
Ø Pay utility service initiation, notification and switching fees Ø Perform customer notification, opt out and transfers
Ø Conduct load forecasting
Ø Establish rates
Ø Legal and regulatory support
Ø Financial management and reporting
SCP has also transitioned from a start-up period using debt to bridge cash-flow requirements to the current period where the agency carries no debt. The agency utilizes cash to post collateral for energy and resource adequacy purchases, and has built up over $25 million in cash reserves to reduce risk. 16 October 2016
Staffing and Contract Services
Personnel in the form of SCP staff or contractors will be added incrementally to match workloads involved in the organization, managing contracts, and managing customer outreach/marketing. SCP currently has 14 staff and will grow to around 18 over the next two years.

Capital Requirements
SCP requires capital for three major functions: (1) staffing and contractor costs; (2) other normal business expenses; and (3) working capital and collateral for energy and resource adequacy purchases. Each of these functions and associated capital requirements are discussed below. The finance plan in Chapter 7 provides a more detailed discussion of the capital requirements and Program finances.

After all current debts and liabilities are subtracted from assets, SCP finances as of July 31, 2016 are strong, with a net position of $41 million.

Operating revenues from sales of electricity are remitted to SCP beginning approximately sixty days after providing energy. This lag is due to the distribution utility’s standard meter reading cycle of 30 days and a 30‑day payment/collections cycle. SCP uses its cash to pay energy and resource adequacy costs while waiting for bill payments from customers.

No borrowing will be needed to expand SCP’s territory into Mendocino County, as SCP has sufficient cash on hand to cover the timing delay between energy expenses and customer receipts.

Financing Plan
The initial start-up funding to launch SCP was provided via a bank credit facility that was established in 2013 and was paid off in 2015. SCP currently carries no debt.
17 October 2016
CHAPTER 5 – Customer Enrollment Phasing
SCP enrolled its existing customers in three phases, beginning with most commercial customers in May 2014, and extending to all remaining customers in SCP’s initial territory in December 2014. The third enrollment of customers in Cloverdale, Petaluma and Rohnert Park was in June 2015. Customers in Mendocino County will be enrolled in June 2017.

SCP has 193,248 active customer accounts and will offer service to approximately 44,106 additional customer accounts in 2017. SCP forecasts total participation to be at about 88% of eligible customers based on experience with our current customers, meaning that about 12% of eligible customers are expected to opt out and continue to receive bundled service from PG&E.
18 October 2016
CHAPTER 6 - Load Forecast and Resource Plan
Introduction
This Chapter describes the planned mix of electric resources and demand reduction programs that will meet the energy needs of SCP’s customers using a highly renewable, low greenhouse gas emission, diversified portfolio of electric sources.

Several overarching policies govern the resource plan and the ensuing resource procurement activities that will be conducted in accordance with the plan. These key polices are as follows:
• Reduce total greenhouse gas emissions.
• Help customers stabilize and reduce total energy costs. • Benefit the local economy through investment in infrastructure and energyrelated programs. • Increase the portion of energy provided by diverse and well-integrated renewable electric sources.

SCP’s current resource mix includes a renewable energy content of 40% and greenhouse gas emissions about 45% below PG&E’s mix. As the SCP Program moves forward, incremental further reductions in the use of fossil fuel sources will be made based on resource availability and cost. Rather than focusing on increases to the percentage of qualifying renewable resources, SCP has shifted to focus more on reducing total GHG emissions. This change in focus is documented in SCP’s draft Resource Plan available at SonomaCleanPower.org, a document that will be redrafted as part of SCP’s Integrated Resource Plan due in 2017.

SCP seeks to supply customers with local renewable resources to the greatest extent practical, recognizing that local renewable resource development must be weighed with the goal of maintaining competitive rates. SCP’s Integrated Resource Plan will also establish ambitious targets for improving customer side load management and energy efficiency as methods of helping reduce customer costs and total greenhouse gas emissions.

The Resource Plan describes how SCP accomplishes the following:

Ø Procure energy needed to offer two generation rate tariffs: 100 percent local renewable and 40 percent renewable through contracts with experienced, financially stable energy suppliers.
19 October 2016
Ø Continue decreasing GHG emissions and increasing minimum renewable energy supplies based on resource availability and economic goals of the program.

Ø Administer customer programs to reduce net electricity purchases by 1%- 2%, consistent with best practices in the industry.

Ø Encourage distributed renewable generation through a standardized power purchase agreement or “Feed-In Tariff”, an enhanced net energy metering tariff, and technical support for innovative generation projects.

SCP must comply with regulatory rules applicable to California load serving entities.

SCP currently contracts with Constellation and Shell to perform the necessary scheduling services to ensure sufficient electric supplies are available to meet the hour-by-hour demands of its customers. SCP adheres to capacity reserve requirements established by the CPUC and the CAISO designed to address uncertainty in load forecasts and potential supply disruptions caused by generator outages and transmission contingencies. In addition, SCP is responsible for ensuring that its resource mix contains sufficient production from qualifying renewable energy resources needed to comply with the statewide RPS (For 2016, 25% renewable energy supply and increasing to 33% by 2020 and 50% by 2030).

SCP’s Resource Plan meets or exceeds all of the applicable regulatory requirements related to resource adequacy and the RPS.

Resource Plan Overview
To meet SCP’s objectives and satisfy the applicable regulatory requirements pertaining to SCP’s status as a California load serving entity, SCP’s Resource Plan includes a diverse mix of power purchases, renewable energy, new customer energy efficiency programs, demand response, and distributed generation. A diversified resource plan minimizes risk and volatility that can occur from overreliance on a single resource type or fuel source, and thus increases the likelihood of rate stability. The ultimate goal of SCP’s Resource Plan is to minimize customer energy costs and greenhouse gas emissions associated with sources of energy.

SCP's power portfolio consists of a broad mix of short and long-term contracts for diverse third-party owned sources, and may include renewable generation assets owned by SCP in the future if and when federal tax laws change so that private ownership is no longer heavily incentivized.

While SCP is currently solely focused on contracting with third parties to produce power, it may explore opportunities in the future for investment in renewable generating assets, subject to then-current market conditions, statutory requirements and regulatory considerations. Any renewable generation owned by SCP or controlled under long-term power purchase agreement with a proven public power developer, could provide a portion of SCP’s electricity requirements on a 20 October 2016
cost-of-service basis. Depending upon market conditions and, importantly, the applicability of future changes in tax incentives for renewable energy development, electricity purchased under a cost-of-service arrangement may be more costeffective than purchasing renewable energy from third party developers. Any investment decisions will be made following thorough environmental reviews and in consultation with qualified financial and legal advisors.

SCP’s Resource Plan will integrate supply-side resources with programs that will help customers reduce their energy costs through improved energy efficiency and other demand-side measures. As part of its Resource Plan, SCP will actively pursue, promote and ultimately administer a variety of customer energy efficiency programs that can cost-effectively displace supply-side resources and impacts.

The following table provides a status of SCP’s current major supply agreements:

Contract
Name
Description Term
Phase 1/1A Bundled Conventional, Carbon-Free, and
Renewable Energy and Resource Adequacy
contract to meet Phase 1 load.
5/2014 through
12/2016
Phase 2
(2016)
Bundled Conventional, Carbon-Free, and
Renewable Energy contract to meet Phase 2
load in 2016.
1/2016 through
12/2016
Geysers 1 10-Year Bundled Geothermal and RA.

Local. 10 MW in 2014 up to 18 MW in 2020.
5/2014 through
12/2023
Geysers 2 10-Year Bundled Geothermal and RA.

Adds to Geysers 1 to achieve 30 MW in 2017
and 50 MW from 2018 through 2026.
1/2017 through
12/2026
Geysers 3 1-Year, 65,000 MWh Bundled Geothermal. 1/2015 through 12/2015
Shaped
(2017-2020)
Shaped Energy contract to meet load from
2017 through 2020
1/2017 through
12/2020
Carbon-Free
(2017-2020)
Carbon-Free Energy contract. 1/2017 through
12/2020
Bundled
Renewable
Energy
(2017-2020)
Bundled Renewable Energy for Renewable
Portfolio Standard (RPS).
1/2017 through
12/2020
Mustang 1 20-Year, 30 MW New Solar PV. 1/2017 through
12/2036
21 October 2016
Mustang 3 20-Year, Additional 40 MW New Solar PV. 1/2017 through 12/2036
Mustang 4 1-Year, Additional 30 MW Solar PV. 1/2017 through 12/2017
Floating
Solar
25-year, Additional 9 MW New Local Solar PV. 9/2017 through 8/2042
Floating
Solar
25-year, Additional 3.5 MW New Local Solar PV. 3/2019 through 2/2044
SCP’s proposed resource plan for the years 2014 through 2023 is summarized in the following table:

Supply Requirements
SCP’s projected electric consumption is evaluated on an hourly basis, and matched with resources best suited to serving the aggregate of hourly demands or the program’s “load profile.” SCP’s rollout plan and assumptions regarding customer participation rates are discussed below.
2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
SCP Demand (GWh)
Retail Demand 581 1,987 2,215 2,454 2,621 2,630 2,639 2,648 2,657 2,667 Losses and UFE 35 119 133 147 157 158 158 159 159 160
Total Demand 616 2,106 2,348 2,601 2,778 2,788 2,797 2,807 2,817 2,827 SCP Supply (GWh)
Renewable Resources 36% 37% 39% 41.0% 45.0% 47.0% 50.0% 52.0% 54.0% 56.0% Power Purchase Contracts 209 726 874 1,006 1,179 1,236 1,319 1,377 1,435 1,493 Total Renewable Resources 209 726 874 1,006 1,179 1,236 1,319 1,377 1,435 1,493 Carbon-Neutral Resources 44% 41% 36% 41% 38% 37% 34% 34% 34% 34% Power Purchase Contracts 258 815 792 1,006 996 960 897 900 904 907 Total Carbon Neutral Resources 258 815 792 1,006 996 960 897 900 904 907 Conventional Resources
Power Purchase Contracts 149 566 682 589 603 592 581 530 478 427 Total Conventional Resources 149 566 682 589 603 592 581 530 478 427 Total Supply -616 -2,106 -2,348 -2,601 -2,778 -2,788 -2,797 -2,807 -2,817 -2,827 SCP SCP + Mendocino
Proposed Resource Plan
(GWH)
2014 to 2023
Sonoma Clean Power
22 October 2016
Customer Participation Rates
Customers will be automatically enrolled in the SCP Program unless they opt out during the customer notification process conducted during the 60-day period prior to enrollment and continuing through the 60-day period following commencement of service. SCP anticipates an overall customer participation rate of approximately 88 percent of PG&E bundled service customers, based on actual opt-out rates for SCP’s current customers. SCP does not automatically enroll direct access service customers.

The participation rate is not expected to vary significantly among customer classes, in part due to the fact that SCP will offer two distinct rate tariffs that will address the needs of cost-sensitive customers as well as the needs of both residential and business customers that prefer a highly renewable energy product. The assumed participation rates will continue to be refined as SCP’s rollout to new customers continues.

Customer Forecast
Once new customers are enrolled, they will be switched over to service by SCP on their regularly scheduled meter read date over an approximately thirty day period.

SCP assumes that customer growth will generally be offset by customer attrition (opt-outs) and energy efficiency improvements over time, resulting in a relatively stable customer base (0.1% annual growth) over the noted planning horizon.

Because CCA in California has a relatively short history, it is very difficult to anticipate with any precision the actual levels of customer participation within the SCP Program. SCP believes that its assumptions regarding the offsetting effects of growth and attrition are reasonable in consideration of the historical customer growth within Sonoma County and the potential for continuing customer opt-outs following mandatory customer notification periods. The forecast of service accounts (customers) served by SCP for each of the next ten years is shown in the following table:
2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
Customers
Residential 140,819 170,096 167,251 199,882 200,081 200,281 200,481 200,681 200,881 201,081 Small Commercial 13,583 17,559 17,670 22,263 22,285 22,307 22,329 22,351 22,373 22,395 Medium Commercial 2,335 2,953 2,917 3,507 3,510 3,513 3,516 3,519 3,522 3,525 Large Commercial 435 537 549 718 718 718 718 718 718 718 Industrial 9 15 13 15 15 15 15 15 15 15
Street Lighting & Traffic 2,106 2,384 2,342 2,792 2,794 2,796 2,798 2,800 2,802 2,804 Agricultural 2,632 2,505 2,506 3,112 3,115 3,118 3,121 3,124 3,127 3,130 Total 161,919 196,049 193,248 232,289 232,518 232,748 232,978 233,208 233,438 233,668 SCP + Mendocino
Sonoma Clean Power
Retail Service Accounts (End of Year)
2014 to 2023
SCP
23 October 2016
Sales Forecast
The annual electricity needed to serve SCP’s retail customers increases from over 616 GWh in 2014 to approximately 2,780 GWh once all customers in Mendocino County have been receiving service for one year. Annual energy requirements are shown below.

Capacity Requirements
The CPUC’s resource adequacy standards applicable to SCP require a demonstration one year in advance that SCP has secured physical capacity for 90 percent of its projected peak loads for each of the five months May through September, plus a minimum 15 percent reserve margin. On a month-ahead basis, SCP must demonstrate 100 percent of the peak load plus a minimum 15 percent reserve margin. SCP is also subject to the flexible capacity requirements that were implemented in 2015.

A portion of SCP’s capacity requirements must be procured locally, from the Greater Bay area as defined by the CAISO, from local reliability areas outside the Greater Bay Area, and from flexible resources capable of increasing and decreasing output quickly. SCP is required to demonstrate its local capacity requirement for each month of the following calendar year. The local capacity requirement is a percentage of the total (PG&E service area) local capacity requirements adopted by the CPUC based on SCP’s forecasted peak load. SCP must demonstrate compliance or request a waiver from the CPUC requirement as provided for in cases where local capacity is not available.
2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
SCP Demand (GWh)
Retail Demand 581 1,987 2,215 2,454 2,621 2,630 2,639 2,648 2,657 2,667 Losses and UFE 35 119 133 147 157 158 158 159 159 160
Total Demand 616 2,106 2,348 2,601 2,778 2,788 2,797 2,807 2,817 2,827 SCP SCP + Mendocino
Energy Requirements
(GWH)
2014 to 2023
Sonoma Clean Power
24 October 2016
SCP's resource adequacy requirements for 2014-2016 and forecasted requirements for 2017 are shown in the following table:

SCP’s plan ensures that sufficient reserves will be procured to meet its peak load at all times. SCP’s projected annual capacity requirements are shown in the following table:

SCP + Mendo
Month 2014 2015 2016 2017
January - 284 359 303
February - 288 378 292
March - 238 290 275
April - 245 322 306
May 122 240 323 325
June 136 445 433 443
July 125 331 347 420
August 131 422 455 462
September 139 350 431 458
October 128 291 369 389
November 120 336 349 359
December 239 308 356 347
Sonoma Clean Power
Forward Capacity and Reserve Requirements
(MW)
2014 to 2016
SCP
25 October 2016
Local and flexible capacity requirements are functions of the PG&E area resource adequacy requirements and SCP’s projected peak demand. SCP works with the CPUC’s Energy Division and staff at the California Energy Commission to obtain the data necessary to calculate SCP’s monthly local capacity requirement.

SCP has coordinated with PG&E and appropriate state agencies to manage the transition of responsibility for resource adequacy from PG&E to SCP during 2014- 2016. For system resource adequacy requirements, SCP makes month-ahead 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
Demand (MW)
Demand 233 437 462 522 522 523 523 524 524 525
Losses and UFE 7 13 14 16 16 16 16 16 16 16
Total Net Peak Demand 240 450 476 537 538 539 539 540 540 541 Coincident Peak Adjustment -20 -22 -24 -50 -51 -51 -51 -51 -51 -51 Reserve Requirement 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15 0.15 Capacity Reserve Requirement 33 64 68 73 73 73 73 73 73 73 RMR/CAM Allocation -14 -32 -38 -52 -53 -53 -53 -53 -53 -53 EE/DG/DR Adjustment 0 -5 -15 -32 -32 -32 -32 -32 -33 -33 Resource Category DR 0 -10 -12 -13 -13 -13 -13 -13 -13 -13 SCP Capacity Requirement 239 445 455 462 463 463 464 464 465 465 SCP SCP + Mendocino
(MW)
2014 to 2023
Sonoma Clean Power
Capacity Requirements
2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
SCP Capacity Requirement 239 445 455 462 463 463 464 464 465 465 Local Capacity Requirement (% of Peak) 16% 24% 38% 40% 40% 40% 40% 40% 40% 40% Greater Bay Area Share of Local Capacity Requirement (%) 38% 34% 34% 34% 34% 34% 34% 34% 34% 34% Other PG&E Share of Local Capacity Requirement (%) 62% 66% 66% 66% 66% 66% 66% 66% 66% 66% SCP Local Capacity Requirement, Greater Bay Area (MW) 15 37 58 63 63 63 63 63 63 63 SCP Local Capacity Requirement, Other PG&E Area (MW) 24 71 113 122 122 122 122 123 123 123 SCP Local Capacity Requirement, Total (MW) 38 108 171 185 185 185 186 186 186 186 Flexible Capacity Requirement (MW)* N/A 85 98 124 124 124 124 124 124 124 *Flexible Capacity % Requirement Varies By Month (may not coincide with month of peak demand) SCP SCP + Mendocino
Sonoma Clean Power
Local and Flexible Capacity Requirements
(MW)
2014 to 2023
26 October 2016
showings for each month that SCP plans to serve load, and load migration issues are addressed through the CPUC’s approved procedures.

Renewables Portfolio Standards Energy Requirements
Basic RPS Requirements
As a CCA, SCP is required by law and ensuing CPUC regulations to procure a certain minimum percentage of its retail electricity sales from qualified renewable energy resources. For purposes of determining SCP’s renewable energy requirements, the same standards for RPS compliance that are applicable to the distribution utilities apply to SCP.

SCP’s Renewables Portfolio Standards Requirement
SCP’s annual RPS requirements and Program Targets are shown in the table below.

Based on planned renewable energy procurement objectives, SCP anticipates that it will significantly exceed the minimum RPS requirements as shown below.

Purchased Power
Power purchased from utilities, power marketers, public agencies, and/or generators will be a significant source of supply during the first several years. SCP initially contracted to obtain most of its electricity from a third party electric provider. The third party supplier was responsible for procuring a mix of power purchase contracts, including specified renewable energy targets, to provide a stable and cost-effective resource portfolio for the Program. SCP is, however, gradually transitioning to self management of many of these responsibilities through the increasing use of long-term power purchase agreements. In doing so, SCP has improved its ability to provide cleaner, competitively priced power. 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023
Retail Sales 581,294 1,987,001 2,215,212 2,453,689 2,620,557 2,629,729 2,638,933 2,648,169 2,657,438 2,666,739 RPS Requirement (% of Retail Sales) 22% 23% 25% 27% 29% 31% 33% 33% 33% 33% RPS Program Target (% of Retail Sales) 36% 37% 39% 41% 45% 47% 50% 52% 54% 56% RPS Requirement (MWh) 126,141 462,971 553,803 662,496 759,962 815,216 870,848 873,896 876,955 880,024 RPS Program Target (MWh) 209,332 725,861 873,708 1,006,012 1,179,251 1,235,973 1,319,467 1,377,048 1,435,017 1,493,374 Surplus in Excess of RPS (MWh) 83,191 262,890 319,905 343,516 419,289 420,757 448,619 503,152 558,062 613,350 SCP SCP + Mendocino
RPS Requirements and Program Targets
(MWH)
2014 to 2023
Sonoma Clean Power
27 October 2016
Renewable Resources
SCP currently procures most of its renewable power supply from its third party electric suppliers and developers. Long-term PPAs growing to 70 MW of solar, 50 MW of baseload geothermal and 46 MW of wind are executed, and locally, 3 MW of feed-in tariff local solar and 12.5 MW of additional local wholesale solar is also contracted. Renewable projects that are located virtually anywhere in the Western Interconnection can be considered, but SCP has a strong preference for local, regional and California-based projects.

Unbundled Renewable Energy Certificates
SCP has voluntarily chosen to avoid the use of unbundled Renewable Energy Certificates/Credits, except where they may be necessary to support local renewable energy programs or protect the value of California renewable sources, such as during transmissions outages under force majeure.

Energy Efficiency
SCP’s energy efficiency goals reflect a strong commitment to increasing energy efficiency within the County, expanding beyond the savings achieved by PG&E’s programs. SCP seeks to maximize end-use customer energy efficiency by facilitating customer participation in existing utility programs as well as by forming new programs that will displace SCP’s need for traditional electric procurement activities.

Forecast energy efficiency savings equal to 1 percent of SCP’s projected energy sales appears to be a reasonable baseline for the demand-side portion of SCP’s resource plan. For example, the National Action Plan for Energy Efficiency states among its key findings “consistently funded, well-designed efficiency programs are cutting annual savings for a given program year of 0.15 to 1 percent of energy sales.”3 The American Council for an Energy-Efficient Economy (ACEEE) reports for states already operating substantial energy efficiency programs that an energy efficiency goal of one percent, as a percentage of energy sales, is a reasonable level to target.4
These savings would be in addition to the savings achieved by PG&E administered programs. Achieving this goal will mean at least a doubling of energy savings relative to the status quo (without the SCP program). SCP programs will focus on closing the gap between the vast economic potential of energy efficiency within the County and what is actually achieved.

3 National Action Plan for Energy Efficiency, July 2006, Section 6: Energy Efficiency Program Best Practices (pages 5-6) 4 Energy Efficiency Resource Standards: Experience and Recommendations, Steve Nadel, March 2006, ACEEE Report E063 (pages 28 - 30).
28 October 2016
SCP will develop specific energy efficiency programs and may seek program funding from the CPUC to administer these energy efficiency programs. Additional details of SCP’s energy efficiency plan are currently under development.

Demand Response
Demand response programs provide incentives to customers to reduce demand upon request by the load serving entity (i.e., SCP), reducing the amount of generation capacity that must be maintained as infrequently used reserves.

Demand response programs can be cost effective alternatives to procured capacity that would otherwise be needed to comply with California’s resource adequacy requirements. The programs also provide rate benefits to customers who have the flexibility to reduce or shift consumption for relatively short periods of time when generation capacity is most scarce. Like energy efficiency, demand response can be a win/win proposition, providing economic benefits to the electric supplier as well as customer service benefits.

In its ruling on local resource adequacy, the CPUC found that dispatchable demand response resources as well as distributed generation resources should be allowed to count for local capacity requirements. This resource plan anticipates that SCP’s demand response programs would partially offset its local capacity requirements beginning in 2017, and SCP is participating in PG&E’s Demand Response Auction Mechanism for 2017 through the use of aggregated, managed electric vehicle charging stations.

PG&E offers several demand response programs to its customers, and SCP intends to recruit those customers that have shown a willingness to participate in utility programs into PG&E’s programs or added-value similar programs offered by SCP. 5 The goal for this resource plan is to meet 5 percent of the SCP Program’s total capacity requirements through dispatchable demand response programs that qualify to meet local resource adequacy requirements. This goal translates into approximately 18 MW of peak demand enrolled in SCP’s demand response programs. Achievement of this goal would displace approximately 20 percent of SCP’s local capacity requirement within the “Other PG&E” Local Reliability Area. 6 5 These utility programs include the Base Interruptible Program (E-BIP), the Demand Bidding Program (E-DBP), Critical Peak Pricing (E-CPP), Optional Binding Mandatory Curtailment Plan (E-OBMC), the Scheduled Load Reduction Program (E-SLRP), and the Capacity Bidding Program (E-CBP). SCP plans to develop its own demand response programs, which may be similar to those currently administered by the incumbent utility.
6 The California Public Utilities Commission has defined five local Resource Adequacy areas, including the “Other PG&E” local area (which represents an aggregation of various locations within the PG&E service territory), which have been designated as transmission-constrained. Load serving entities, including SCP, must procure a certain portion of their respective resource adequacy obligations from resources located within these transmission-constrained areas. However, demand response programs may be used to directly reduce local resource adequacy obligations; SCP plans to reduce such obligations through the implementation of effective demand response programs. 29 October 2016
SCP intends to adopt a demand response program that enables it to request customer demand reductions during times when capacity is in short supply or spot market energy costs are exceptionally high. The level of customer payments may be set in relation to the cost of local capacity that can be avoided as a result of the customer’s willingness to curtail usage upon request.

Appropriate limits on customer curtailments, both in terms of the length of individual curtailments and the total number of curtailment hours that can be called will be considered SCP’s demand response program design. It will also be important to establish a reasonable measurement protocol for customer performance of its curtailment obligations and deploy technology to automate customer notifications and responses. Performance measurement should include establishing a customer specific baseline of usage prior to the curtailment request from which demand reductions can be measured. SCP utilizes experienced third party contractors to design, implement and administer its demand response programs.

Distributed Generation
Consistent with SCP’s environmental policies and the state’s Energy Action Plan, clean distributed generation is a significant component of the resource plan. SCP will work with state agencies and PG&E to promote deployment of photovoltaic (PV) systems within SCP’s jurisdiction, with the goal of maximizing use of the available incentives that are funded through current utility distribution rates and public benefits surcharges. Two programs already administered by SCP include NetGreen, an improved net energy metering program, and ProFIT, a local feed-in tariff with preferred rates.

NetGreen provides a 1 cent premium on production to net metered customers to make up for SCP’s lower retail rates and also allows customers to carry-over all financial credits (regardless of kWh balances) to future bills. Every May, SCP customers are cashed-out at the retail generation rate, meaning that any customer with a net surplus in April will be paid for the kWh surplus at SCP prevailing generation rate—historically about four times higher than PG&E’s wholesale cashout rate.

ProFIT is SCP’s standard offer feed-in tariff that sets a base rate of $95 per MWh for local Sonoma County sited, qualifying renewable production on systems under 1 MW. Certain bonuses are available up to $35 per MWh for five years, based on use of local workforce, size of system and other factors deemed preferred by the SCPA Board of Directors.

SCP also hopes the CPUC will consider allowing CCAs to self-procure all generation resources deemed necessary for system reliability, such as Combined Heat and Power (CHP). If this regulatory action is taken, SCP believes the development of 30 October 2016
distributed, possibly renewably fueled, CHP in SCP's territory may be possible, and the likelihood of total energy cost reductions for customers is high. 31 October 2016
CHAPTER 7 – Financial Plan for Ongoing Program Operation This Chapter examines the monthly cash flows expected over the next few years of the SCP Program. It also describes the requirements for working capital and longterm financing for the potential investment in renewable generation, consistent with the resource plan contained in Chapter 6.

Description of Cash Flow Analysis
SCP’s cash flow analysis estimates the level of capital that will be required during the phase-in of the newly participating jurisdictions. The analysis focuses on the SCP Program’s monthly costs and revenues and specifically accounts for the enrollment of the new SCP Customers described in Chapter 5.

Cost of CCA Program Operations
The first category of the cash flow analysis is the Cost of CCA Program Operations.

To estimate the overall costs associated with CCA Program Operations, the following components were taken into consideration:

Ø Electricity Procurement;
Ø Ancillary Services Requirements;
Ø Exit Fees;
Ø Staffing and Professional Services;
Ø Data Management Costs;
Ø Administrative Overhead;
Ø Billing Costs;
Ø Uncollectible Electric Bills;
Ø Scheduling Coordination;
Ø Grid Management and other CAISO Charges;
Ø CCA Bond and Security Deposit;
Ø Pre-Startup Cost Reimbursement; and
Ø Debt Service.

Revenues from CCA Program Operations
The cash flow analysis also provides estimates for revenues generated from CCA operations or from electricity sales to customers. In determining the level of revenues, the analysis assumes the customer enrollment schedule described herein, and assumes that SCP charges its current rates. SCP rate increases of 3% annually, the approximate long-run average increase in California electric utility 32 October 2016
rates, would support the cash flows presented herein.
7 More detail on SCP’s rates
can be found in Chapter 8.

Cash Flow Analysis Through Customer Enrollment
The results of the cash flow analysis provide an estimate of the level of capital required for SCP to complete enrollment of customers in the newly participating jurisdictions. This estimated level of capital is determined by examining the monthly cumulative net cash flows (revenues from CCA operations minus cost of CCA operations) based on assumptions for payment of costs or other cash requirements (e.g., deposits) by SCP, along with estimates for when customer payments will be received. This identifies, on a monthly basis, what level of cash flow is available in terms of a surplus or deficit.

The cash flow analysis identifies funding requirements in recognition of the potential lag between payments received and payments made during the phase-in period.

Financing requirements for the startup period through the end of 2014, including working capital needs was approximately $6.5 million. That amount was initially borrowed from a bank, but has since be entirely repaid. SCP has no borrowing needs to support cash flow needs associated with the power purchases for expanding to Mendocino County, and forecasts a net positive cash flow through the preparation and start of service to the new territory.

CCA Program Implementation Financials
A financial analysis of the next several years of SCP operation is shown in the following table. Assuming annual generation rate increases equal to 2%, the CCA program is projected to accrue a reserve account balance of approximately $50 million through the end of 2020. Note, however, that actual figures will vary with adopted rate increases and costs of energy as well as numerous other business expenses, such as staffing, rent, insurance, etc.

7 According to the California Energy Commission Utility-wide Weighted Average Electric Utility Prices report, PG&E average electric rates have increased by an average of 4.6% per year since 2000 and

3.4% annually since 2005.
33 October 2016
The surpluses achieved during the phase-in period serve to build SCP’s credit profile in order to lower the average cost of energy. Actual financial performance will vary from these projections, and will significantly depend on actual energy costs and adopted rates.
34 October 2016
CHAPTER 8 - Ratesetting and Program Terms and Conditions Introduction
This Chapter describes the policies adopted by SCP in setting its rates for electric aggregation services. These include policies regarding rate design, rate objectives, and provision for due process in setting Program rates. Program rates are ultimately approved by the SCPA Board of Directors with input from the Customer Advisory Committee. The Board has authority to modify its governing policies from time to time at its discretion.

Rate Policies
SCP will generally establish rates sufficient to recover all costs related to operation of the SCP Program, including any reserves that may be required as a condition of financing and other discretionary reserve funds that may be approved by the Board.

As a general policy, rates will be uniform for all similarly situated customers enrolled in the SCP Program throughout the service area of SCP.

The primary objectives of the ratesetting plan are to set rates that achieve the following:

Ø 100 percent local, 100 percent renewable energy supply option “EverGreen”; Ø Rate competitive tariff option “CleanStart”;
Ø Rate stability;
Ø Equity among customers in each tariff;
Ø Customer understanding; and
Ø Revenue sufficiency.

Each of these objectives is described below.

Rate Competitiveness
SCP's goal is to offer competitive rates for the electric services SCP provides to participating customers. For participants in SCP’s standard tariff called “CleanStart,” the goal is for SCP’s rates to be competitive with (meaning usually lower than) PG&E’s rates. For participants in SCP’s EverGreen 100 percent local and 100 percent renewable energy Tariff, the goal is to offer the lowest possible customer rates that allow for the purchase of such local and renewable energy.

Competitive rates are critical to attracting and retaining key customers. In order for SCP to be successful, the combination of price and value provided by SCP to its customers must be perceived as superior when compared to the bundled utility 35 October 2016
service alternative. The value provided by SCP includes lower greenhouse gas emissions and a higher renewable energy content for its electric supply, enhanced energy efficiency and customer programs, community focus and investment, local control, and the benefits that derive from SCP’s mission to serve its customers rather than the interests of utility shareholders.

As previously discussed, the SCP Program significantly reduces GHG emissions and increases renewable energy supply to program customers, relative to the incumbent utility, by offering two distinct rate tariffs. The default tariff for SCP Program customers is the standard tariff, called “CleanStart,” which minimizes GHG emissions while maintaining generation rates that are comparable (and usually slightly lower than) PG&E’s. The emissions under CleanStart for 2014 were 48% lower than PG&E’s GHG emissions, however, SCP understands that there are large fluctuations in year-to-year GHG emissions relating to available hydropower and other factors. As a result, SCP is committed to providing default CleanStart service that is at least 20% lower in GHG emissions than PG&E’s service.

SCP also offers its customers EverGreen, a voluntary 100% renewable energy tariff, which supplies participating customers with 100 percent locally-produced 100 percent renewable energy at rates that reflect SCP’s actual cost for procuring those energy supplies. Currently, the premium is 2.5 cents per kWh above the CleanStart rate.

Participating qualified low- or fixed-income households, such as those currently enrolled in the California Alternate Rates for Energy (CARE) program, are automatically enrolled in the standard CleanStart Tariff and will continue to receive related discounts on monthly electricity bills through PG&E.

Rate Stability
SCP offers stable rates by hedging its supply costs a broad mix of contract length (short, medium and long) and by including renewable energy sources with stable contract costs. Rate stability considerations may prevent SCP Program rates from directly tracking similar rates offered by the distribution utility, PG&E, and may result in differences from the general rate-related targets initially established for the SCP Program. SCP endeavors to maintain general rate parity with PG&E to ensure that SCP rates are not drastically different from the competitive alternative.

Equity among Customer Classes
SCP’s rates are set based on an estimate of cost-of-service considerations by referencing the rates customers would otherwise pay to PG&E. Rate differences among customer classes reflect the rates charged by the local distribution utility as well as differences in the costs of providing service to each class. Rate benefits may also vary among customers within the major customer class categories, depending upon the specific rate designs adopted by the Board. Over time, SCP may explore 36 October 2016
differentiating its rate structure from PG&E’s to support program goals, such as increased use of renewable energy or conservation.

Customer Understanding
The goal of customer understanding involves rate designs that are relatively straightforward so that customers can readily understand how their bills are calculated. This not only minimizes customer confusion and dissatisfaction but will also result in fewer billing inquiries to SCP’s customer service call center. Customer understanding also requires rate structures to reflect rational rate design principles (i.e., there should not be differences in rates that are not justified by costs or by other policies such as providing incentives for conservation).

Revenue Sufficiency
SCP’s rates must collect sufficient revenue from participating customers to fully fund SCP’s annual budget minus any use of program reserves approved by the SCPA Board of Directors. Rates are set to collect the adopted budget based on a forecast of electric sales for the budget year. Rates are adjusted as necessary to maintain the ability to fully recover all of SCP’s costs, subject to the disclosure and due process policies described later in this chapter.

Rate Design
SCP generally matches the rate structures from the utilities’ standard rates to avoid the possibility that customers would see significantly different bill impacts as a result of changes in rate structures when beginning service in SCP’s program. SCP may, however, also introduce new rate options for customers, such as rates designed to encourage customer installation of renewable energy, economic expansion or business retention within SCP’s service area.

SCP’s current customer total electric charges are between 1% and 5% lower than PG&E’s bundled customer charges, when comparing total bills with all generation, transmission and distribution and PG&E fees. SCP customers’ total electric charges are subject to change throughout the year due to the fact that SCP customers continue to pay all non-generation electric charges to PG&E, and these charges are subject to frequent adjustment. SCP customers also pay a Power Charge Indifference Adjustment (“PCIA”) to ensure that PG&E’s remaining customers do not have any increased costs as a result of SCP. There is currently no adopted method to ensure that costs are not shifted from bundled customers onto SCP’s customers, so this remains the chief operational risk to SCP to ensure that an effective procedure is eventually implemented to achieve this requirement.

All cost comparisons SCP makes with PG&E are inclusive of all electric charges including transmission, distribution, public purpose, nuclear decommissioning, etc., meaning that SCP only compares the bottom line cost information rather than the 37 October 2016
generation component by itself. The PCIA is identified in each of PG&E’s rate schedules.

Custom Pricing Options
SCP may work to develop specially tailored rate and electric service products that meet the specific load characteristics or power market risk profiles of larger commercial and industrial customers. This would allow such customers to have access to a wider range of products than is currently available under the incumbent utility and potentially reduce the cost of power for these customers. SCP may provide large energy users with custom pricing options to help these customers gain greater control over their energy costs. Some examples of potential custom pricing options are rates that are based on an observable market index (e.g., CAISO prices) or fixed priced contracts of various terms.

Net Energy Metering
Customers with on-site generation eligible for net metering from PG&E may participate in NetGreen, offered by SCP. NetGreen allows for customers with certain qualified solar or wind distributed generation to be billed on the basis of their net energy costs. The PG&E net metering tariff (E-NEM) requires the CCA to offer a net energy metering tariff in order for the customer to continue to be eligible for service on Schedule E-NEM. SCP’s NetGreen tariff applies to the generation component of the bill, and the PG&E net energy metering tariff only applies to the utility’s portion of the bill. SCP pays customers for excess power produced from net energy metered generation systems in accordance with the rate designs adopted by the SCPA Board.

SCP may also implement tariff and financing programs to provide incentives to residents and businesses to maximize the size of photovoltaic and other renewable energy systems in order to increase the amount of locally-produced renewable power. Current tariffs create an incentive for residents and businesses considering new PV or renewable systems to limit the size of those systems so that annual generation matches annual on-site load. By implementing tariffs and programs to provide an incentive to maximize the output of such systems, SCP can help to increase the amount of local PV and renewable generation with minimal impact on the environment or existing infrastructure.

Disclosure and Due Process in Setting Rates and Allocating Costs among Participants
Program rates are established in a public process originating with staff assessment of the revenue requirement, presentation of a combined budget and rate proposal to the Community Advisory Committee, followed by presentation of the draft budget and rates to the Board of Directors. Staff then develop a proposed final budget and set of customer rates based on public feedback, first to the Customer 38 October 2016
Advisory Committee for recommendation and then for adoption to the SCPA Board of Directors.
39 October 2016
CHAPTER 9 – Customer Rights and Responsibilities
This chapter discusses customer rights, including the right to opt out of the SCP Program and the right to privacy of customer usage information, as well as obligations customers undertake upon agreement to enroll in the CCA Program. All customers that do not opt out within 30 days of the fourth enrollment notice will have agreed to become full status program participants and must adhere to the obligations set forth below. The Board retains authority to modify program policies from time to time at its discretion.

Customer Notices
At the initiation of any mass customer enrollment process, a total of four notices is provided to customers describing the Program, informing them of their opt-out rights to remain with utility bundled generation service, and containing a simple mechanism for exercising their opt-out rights. The first notice is mailed to customers approximately sixty days prior to the date of automatic enrollment. A second notice is sent approximately thirty days later. SCP uses its own mailing service for requisite enrollment notices rather than including the notices in PG&E’s monthly bills. This is intended to increase the likelihood that customers will read the enrollment notices, which may otherwise be ignored if included as a bill insert.

Customers may opt out by notifying SCP using SCP’s designated telephone-based or internet opt-out processing service. Should customers choose to initiate an optout request by contacting PG&E, they should be transferred to SCP’s call center to complete the opt-out request. Consistent with CPUC regulations, notices returned as undelivered mail would be treated as a failure to opt out, and the customer is automatically enrolled.

Following automatic enrollment, a third enrollment notice is mailed to customers, and a fourth and final enrollment notice will be mailed 30 days after automatic enrollment. Opt-out requests made on or before the sixtieth day following start of SCP service will result in customer transfer to bundled utility service with no penalty. Such customers will be obligated to pay charges associated with the electric services provided by SCP during the time the customer took service from the SCP Program, but will otherwise not be subject to any penalty or transfer fee from SCP.

Customers who establish new electric service accounts within the Program’s existing service area will be automatically enrolled in the SCP Program and will have sixty days from the start of SCP service to opt out if they so desire. Such customers will be provided with two enrollment notices within this sixty-day post enrollment period. Such customers will also receive a notice detailing SCP’s privacy 40 October 2016
policy regarding customer usage information. SCP’s Board of Directors has the authority to implement entry fees for customers that initially opt out of the Program, but later decide to participate, however, the SCPA Board does not currently impose any such fees.

Termination Fee
Customers that are automatically enrolled in the SCP Program can elect to transfer back to the incumbent utility without penalty within the first two months of service.

After this free opt-out period, customers will be allowed to terminate their participation subject to payment of a Termination Fee. The Termination Fee applies to all SCP customers that elect to return to bundled utility service or elect to take “direct access” service from an energy services provider. Customers that relocate within the SCP service territory have their CCA service continued at the new address. If a customer relocating to an address within the SCP service territory elected to cancel CCA service, the Termination Fee will apply. Program customers that move out of the SCP service territory would not be subject to the Termination Fee.

PG&E will collect the Termination Fee from returning customers as part of the final bill to the customer from the CCA Program.

The Termination Fee varies by customer class as set forth in the table below, subject to adjustment by the SCPA Board as described below.

SCP Fee for Service Termination
Customer Class Fee
Residential $5
Non-Residential $25
The Termination Fee is clearly disclosed in the four enrollment notices sent to customers during the sixty-day period before automatic enrollment and following commencement of service. The fee could be changed prospectively by SCP’s Board of Directors, subject to SCP’s customer noticing requirements; provided, however, that in no event will any Termination Fee in excess of the amounts set forth above be imposed on any customer leaving before August 1, 2017, except for terminating customers participating in a voluntary tariff. As previously noted, customers that opt out during the statutorily mandated notification period will not pay the Termination Fee that may be imposed by SCP.

Customers electing to terminate service after the initial notification period (that provided them with at least four enrollment notices) are transferred to PG&E on their next regularly scheduled meter read date if the termination notice is received 41 October 2016
a minimum of fifteen days prior to that date. Such customers are also liable for any reentry fees and the Transitional Bundled Rate imposed by PG&E, and are required by PG&E to remain on bundled utility service for a period of one year, as described in PG&E's CCA tariffs.

Customer Confidentiality
Consistent with CPUC regulations, SCP has established policies covering confidentiality of customer data. SCP maintains the confidentiality of individual customers’ names, service addresses, billing addresses, telephone numbers, account numbers, and electricity consumption, except where reasonably necessary to conduct SCP’s business or to provide services to customers, including but not limited to where such disclosure is necessary to (a) comply with the law or regulations; (b) enable SCP to provide service to its customers; (c) collect unpaid bills; (d) obtain and provide credit reporting information; or (e) resolve customer disputes or inquiries. SCP will not disclose customer information for telemarketing, e‐mail, or direct mail solicitation. Aggregate data may be released at SCP’s discretion. SCP handles customer energy usage information in a manner that is fully compliant with the California Public Utility Commission’s required privacy protections for customers of Community Choice Aggregators, as defined in Decision 12-08-045.

Responsibility for Payment
Customers are obligated to pay SCP charges for service provided through the date of transfer including any applicable Termination Fees. Pursuant to current CPUC regulations, SCP is unable to direct that electricity service be shut off for failure to pay SCP’s bill. However, PG&E has the right to shut off electricity to customers for failure to pay electricity bills, and PG&E Electric Rule 23 mandates that partial payments are to be allocated pro rata between PG&E and the CCA. In most circumstances, customers are returned to utility service for failure to pay bills in full. PG&E attempts to collect any outstanding balance from customers in accordance with Rule 23 and the related CCA Service Agreement. The proposed process is for a late payment notice to be provided to the customer within 90 days of the original bill due date. If payment is not received within 30 days from the notice, service will be transferred to the utility on the next regular meter read date, unless alternative payment arrangements have been made. Consistent with the CCA tariffs, Rule 23, service cannot be discontinued to a residential customer for a disputed amount if that customer has filed a complaint with the CPUC, and that customer has paid the disputed amount into an escrow account. 42 October 2016
CHAPTER 10 - Procurement Process
Introduction
This Chapter describes SCP’s procurement process.

Procurement Methods
SCP’s Board of Directors adopts and maintains a policy governing the scale and types of energy transactions allowed and the approval process for those transactions.

SCP enters into agreements for a variety of services needed to support program development, operation and management. SCP generally utilizes competitive procurement methods, particularly for energy and resource adequacy procurement, but may also utilize bilateral procurement or sole source procurement, depending on the nature of the services to be procured. Competitive procurement generally entails a request for offers, request for proposals or similar process. Bilateral procurement is the purchase of goods or services without a direct competitive process when multiple sources of supply are available and easily reviewed. Sole source procurement is generally to be performed only when the circumstances render no other option, such as can occur in an illiquid market such as resource adequacy during some months.

The Chief Executive Officer or Director of Power Services reports to the SCPA Board a summary of the actions taken with respect to energy transactions at the next SCPA Board meeting.

Authority for terminating agreements generally mirrors the authority for entering into such agreements.

Key Contracts
Electric Supply Contracts
SCP initiated service using a multi-year electricity supply contract with a qualified provider, and has subsequently entered into numerous contracts with additional providers to supply energy, renewables, specified source low/zero carbon energy and resource adequacy products. Since SCP’s launch, the agency has executed energy related contracts with at least 18 companies.
43 October 2016
Data Management Contract
A data manager provides the retail customer services of billing and other customer account services (electronic data interchange or EDI with PG&E, billing, remittance processing, and account management). The data management contract is separate from the electric supply contract, and includes the following services:

Ø Data exchange with PG&E;
Ø Technical testing;
Ø Customer information system;
Ø Customer call center;
Ø Billing administration/retail settlements;
Ø Settlement quality meter data reporting; and
Ø Reporting and audits of utility billing.

Separation of the data management contract from the energy supply contract gives SCP greater flexibility to change energy suppliers, if desired, without facing an expensive data migration issue.

SCP executed a five-year contract for data management services in late-2013. 44 October 2016
CHAPTER 11 – Contingency Plan for Program Termination
Introduction
This Chapter describes the process to be followed in the case of SCP Program termination. The termination plan follows the requirements set forth in PG&E’s tariff Rule 23 governing service to CCAs. The Board retains authority to modify program policies from time to time at its discretion.

Termination by SCP
SCP offers CCA services for the long term with no planned Program termination date. In the unanticipated event that the majority of the participating jurisdictions decide to terminate the Program, each governing body would be required to adopt a termination ordinance or resolution and provide adequate notice to the SCPA Board consistent with the terms set forth in the JPA Agreement. Following such notice, the SCPA Board would vote on Program termination subject to voting provisions as described in the JPA Agreement. In the event that the Board affirmatively votes to proceed with JPA termination, the Board would disband under the provisions identified in its JPA Agreement.

After any applicable restrictions on such termination have been satisfied, notice would be provided to customers six months in advance that they will be transferred back to PG&E. A second notice would be provided during the final sixty-days in advance of the transfer. The notice would describe the applicable distribution utility bundled service requirements for returning customers then in effect, such as any transitional or bundled portfolio service rules.

At least one year of advance notice would be provided to PG&E and the CPUC before transferring customers, and SCP would coordinate the customer transfer process to minimize impacts on customers and ensure no disruption in service.

Once the customer notice period is complete, customers would be transferred en masse on the date of their regularly scheduled meter read date.

SCP has posted a CPUC bond to pay for potential transaction fees charged to the Program for switching customers back to distribution utility service. Reserves would be maintained against the fees imposed for processing customer transfers.

Termination by Members
The JPA Agreement defines the terms and conditions under which Members may terminate their participation in the program.

October 2016
CHAPTER 12 – Appendices
Appendix A: SCPA Board Certification of this Plan
Appendix B: SCP New Participant Ordinances
Appendix C: Sonoma Clean Power Joint Powers Agreement
October 2016
Appendix A: SCPA Board Certification of this Plan

October 2016
Appendix B: SCP New Member Ordinances

BEFORE THE CITY COUNCIL OF THE CITY OF FORT BRAGG

AN ORDINANCE AUTHORIZING THE

IMPLEMENTATION OF A

COMMUNITY CHOICE

AGGREGATION PROGRAM BY

PARTICIPATING WITH THE SONOMA

CLEAN POWER AUTHORITY
ORDINANCE NO. 925-2016
The City Council of the City of Fort Bragg ordains as follows:

SECTION 1. The City of Fort Bragg has been actively investigating options to provide electric services to constituents within its service area with the intent of achieving greater local involvement over the provision of electric services and promoting competitive and renewable energy.

SECTION 4. On October 4, 2013, the California Public Utilities Commission certified the "Implementation Plan" for SCPA's CCA program and on February 20, 2015, approved a First Revised and Updated Implementation Plan, confirming SCPA's compliance with the requirements of the Act.

SECTION 5. On June 16, 2015, the Board of Supervisors of Mendocino County adopted Ordinance No. 4337, determining that implementation of a CCA program is in the public interest and welfare of its residents, and elected to authorize and implement a CCA program within the unincorporated areas of the County of Mendocino; and on September 13, 2016, the Board of Supervisors of Mendocino County adopted Ordinance No. 4363, authorizing the implementation of the SCPA's CCA program within the unincorporated areas of Mendocino County.

SECTION 6. On April 11, 2016 and September 12, 2016, the City Council of the City of Fort Bragg heard presentations and received public comment regarding SCPA's CCA program.

In order to participate in SCPA's CCA program, the Act requires the City of Fort Bragg to adopt an ordinance electing to implement SCPA's CCA program in its jurisdiction.

SECTION 7. Based upon all of the above, the City Council of the City of Fort Bragg elects to implement a Community Choice Aggregation program within the City of Fort Bragg, through the City's participation as a "Participant" in the SCPA CCA program as defined in the 1 SCPA Joint Powers Agreement. The City Manager is hereby authorized to execute any documents necessary for the City's participation in the program.

SECTION 8. If any section, subsection, sentence, clause, phrase or word of this Ordinance is for any reason held to be invalid by a court of competent jurisdiction, such decision shall not affect the validity of the remaining portions of this Ordinance. The City Council of the City of Fort Bragg hereby declares it would have passed and adopted this Ordinance and each and all provisions hereof irrespective of the fact that any one or more of said provisions be declared invalid.

SECTION 9. This ordinance shall be and the same is hereby declared to be in full force and effect from and after thirty (30) days after the date of its passage. Within fifteen (15) days after the passage of this Ordinance, the City Clerk shall cause a summary of said Ordinance to be published as provided in Government Code §36933, in a newspaper of general circulation published and circulated in the City of Fort Bragg, along with the names of the City Councilmembers voting for and against its passage.

The foregoing Ordinance was introduced by Councilmember Cimolino at a regular meeting of the City Council of the City of Fort Bragg held on September 26, 2016, and adopted at a regular meeting of the City of Fort Bragg held on October 11, 2016, by the following vote:

AYES: Councilmember Cimolino, Deitz, Peters, and Mayor Turner.

NOES: None.

ABSENT: Councilmember Hammerstrom.

ABSTAIN: None.

RECUSED: None.

Dave Tuner
Mayor
ATTEST:

VAL
June emos
City lerk
PUBLISH: September 29, 2016 and October 20, 2016 (by summary).

EFFECTIVE DATE: November 10, 2016.
2 October 2016
Appendix C: Sonoma Clean Power Joint Powers Agreement
The second amended and restated joint powers agreement adopted on October 13, 2016 begins on the following page.

Approved October 13, 2016 1
Third Amended and Restated Joint Powers Agreement
Relating to and Creating the
Sonoma Clean Power Authority
By and Among
The County of Sonoma and
The Sonoma County Water Agency
This Third Amended and Restated Joint Powers Agreement (“Agreement”), effective as of October 13, 2016, is made and entered into pursuant to the provisions of Title 1, Division 7, Chapter 5, Article 1 (Sections 6500 et seq.) of the California Government Code relating to the joint exercise of powers among the parties set forth in Exhibit B (“Parties”), and, as of this date, supersedes the original Joint Powers Agreement dated December 4, 2012, the First Amended and Restated Joint Powers Agreement dated June 25, 2013, and the Second Amended and Restated Joint Powers Authority dated July 25, 2013.

RECITALS
A. The Parties share various powers under California law, including but not limited to the power to generate, buy and sell power and aggregate electric load for themselves and customers within their jurisdictions.

B. In 2006, the State Legislature adopted AB 32, the Global Warming Solutions Act, which mandates a reduction in greenhouse gas emissions in 2020 to 1990 levels. The California Air Resources Board is promulgating regulations to implement AB 32 which will require local governments to develop programs to reduce greenhouse gas emissions.

C. The purposes for the entering into this Agreement include a. Reducing greenhouse gas emissions in Sonoma County and neighboring regions; b. Providing electric power and other forms of energy to customers at a competitive cost;
c. Carrying out programs to reduce total energy consumption; d. Stimulating and sustaining the local economy, including by developing or promoting local distributed energy resources; and
e. Promoting long-term electric rate stability, energy security, reliability, and resilience.

D. It is the intent of this Agreement to promote the development and use of a wide range of renewable energy sources and energy efficiency programs, including but not limited to Approved October 13, 2016 2
solar, wind, geothermal, and biomass energy production, with a preference for local distributed sources and California sources.

E. The Parties have established a separate public agency, known as the Sonoma Clean Power Authority (“Authority”), under the provisions of the Joint Exercise of Powers Act of the State of California (Government Code Section 6500 et seq.) (“Act”) in order to collectively study, promote, develop, conduct, operate, and manage energy programs.

F. The Parties have adopted an ordinance electing to implement through the Authority a common Community Choice Aggregation program, an electric service enterprise available to cities, counties, and the Sonoma County Water Agency pursuant to California Public Utilities Code Sections 331.1(c) and 366.2 (“CCA Program”).

AGREEMENT
NOW, THEREFORE, in consideration of the mutual promises, covenants, and conditions hereinafter set forth, it is agreed by and among the Parties as follows:

ARTICLE 1: DEFINITIONS AND EXHIBITS

1.1 Definitions. Capitalized terms used in the Agreement shall have the meanings specified in Exhibit A, unless the context requires otherwise.

1.2 Documents Included. This Agreement consists of this document and the following exhibits, all of which are hereby incorporated into this Agreement.

Exhibit A: Definitions
Exhibit B: List of the Parties and Participants
Exhibit C: Annual Energy Use and Voting Shares
ARTICLE 2: FORMATION OF SONOMA CLEAN POWER AUTHORITY

2.1 Effective Date and Term. This Agreement became effective, and the Sonoma Clean Power Authority commenced existence as a separate public agency, on December 4, 2012 (the “Effective Date”). The Authority shall continue to exist, and this Agreement shall be effective, until this Agreement is terminated in accordance with Section 7.4, subject to the rights of the Parties to withdraw from the Authority.

2.2 Formation. There is formed as of the Effective Date a public agency named the Sonoma Clean Power Authority. Pursuant to Sections 6506 and 6507 of the Act, the Authority is a public agency separate from the Parties. Pursuant to Sections 6508.1 of the Act, the debts, liabilities or obligations of the Authority shall not be debts, liabilities or obligations of the individual Parties unless the governing board of a Party agrees in writing to assume any of the debts, liabilities or obligations of the Authority. A Party who has not agreed to assume an Authority debt, liability or obligation shall not be responsible in any way for such debt, liability or obligation even if a majority of the Parties agree to assume the debt, liability or obligation of the Authority.

Notwithstanding Section 8.4 of this Agreement, this Section 2.2 may not be amended unless such amendment is approved by the governing board of each Party.

Approved October 13, 2016 3

2.3 Purpose. The purpose of this Agreement is to establish an independent public agency in order to exercise powers common to each Party to study, promote, develop, conduct, operate, and manage energy, energy efficiency and conservation, and other energy-related programs, and to exercise all other powers necessary and incidental to accomplishing this purpose. Without limiting the generality of the foregoing, the Parties intend for this Agreement to be used as a contractual mechanism by which the Parties and Participants are authorized to participate in the CCA Program, as further described in Section 5.1. The Parties intend that other agreements shall define the terms and conditions associated with the implementation of the CCA Program and any other energy programs approved by the Authority.

2.4 Powers. The Authority shall have all powers common to the Parties and such additional powers accorded to it by law. The Authority is authorized, in its own name, to exercise all powers and do all acts necessary and proper to carry out the provisions of this Agreement and fulfill its purposes, including, but not limited to, each of the following powers, subject to the voting requirements set forth in Section 4.7 through 4.7.6:

2.4.1 to make and enter into contracts;

2.4.2 to employ agents and employees, including but not limited to a Chief Executive Officer;

2.4.3 to acquire, contract, manage, maintain, and operate any buildings, infrastructure, works, or improvements;

2.4.4 to acquire property by eminent domain, or otherwise, except as limited under Section 6508 of the Act, and to hold or dispose of any property;

2.4.5 to lease any property;

2.4.6 to sue and be sued in its own name;

2.4.7 to incur debts, liabilities, and obligations, including but not limited to loans from private lending sources pursuant to its temporary borrowing powers such as Government Code Sections 53850 et seq. and authority under the Act;

2.4.8 to form subsidiary or independent corporations or entities, if necessary to carry out energy supply and energy conservation programs at the lowest possible cost or to take advantage of legislative or regulatory changes;

2.4.9 to issue revenue bonds and other forms of indebtedness;

2.4.10 to apply for, accept, and receive all licenses, permits, grants, loans or other aids from any federal, state, or local public agency;

2.4.11 to submit documentation and notices, register, and comply with orders, tariffs and agreements for the establishment and implementation of the CCA Program and other energy programs;

2.4.12 to adopt rules, regulations, policies, bylaws and procedures governing the operation of the Authority (“Operating Rules and Regulations”); and Approved October 13, 2016 4

2.4.13 to make and enter into service agreements relating to the provision of services necessary to plan, implement, operate and administer the CCA Program and other energy programs, including the acquisition of electric power supply and the provision of retail and regulatory support services.

2.5 Limitation on Powers. As required by Government Code Section 6509, the power of the Authority is subject to the restrictions upon the manner of exercising power possessed by the Sonoma County Water Agency.

2.6 Compliance with Local Zoning and Building Laws and CEQA. Unless state or federal law provides otherwise, any facilities, buildings or structures located, constructed, or caused to be constructed by the Authority within the territory of the Authority shall comply with the General Plan, zoning and building laws of the local jurisdiction within which the facilities, buildings or structures are constructed and comply with the California Environmental Quality Act (CEQA).

ARTICLE 3: AUTHORITY PARTICIPATION

3.1 Participation in CCA Program. The Parties may participate in the CCA Program upon the adoption of an ordinance required by Public Utilities Code Section 366.2(c)(12). Other incorporated municipalities and counties (“Participants”) may participate in the CCA Program upon (a) the adoption of a resolution by the governing body of such incorporated municipality or such county requesting that the incorporated municipality or county, as the case may be, become a participant in the CCA Program, (b) the adoption, by an affirmative vote of the Board satisfying the requirements described in Section 4.7.3 (or, if demanded by any Director, 4.7.4), of a resolution authorizing the participation of the additional incorporated municipality or county, specifying the participation payment, if any, to be made by the additional incorporated municipality or county to reflect its pro rata share of organizational, planning, and other preexisting expenditures, and describing additional conditions, if any, associated with participation, (c) the adoption of an ordinance required by Public Utilities Code Section 366.2(c)(12) and execution of any necessary program agreements by the incorporated municipality or county, (d) payment of the membership payment, if any, and (e) satisfaction of any conditions established by the Board.

3.2 Continuing Participation. The Parties acknowledge that participation in the CCA Program may change by the addition or withdrawal or termination of Participants. The Parties agree to participate with such other Participants as may later be added, as described in Section 3.1. The Parties also agree that the withdrawal or termination of a Participant shall not affect this Agreement or the remaining Parties’ or Participants’ continuing obligations under this Agreement.

3.3 Participants Not Liable for Authority Debts. The debts, liabilities or obligations of the Authority shall not be debts, liabilities or obligations of the individual Participants unless the governing board of a Participant agrees in writing to assume any of the debts, liabilities or obligations of the Authority. A Participant who has not agreed to assume an Authority debt, liability or obligation shall not be responsible in any way for such debt, liability or obligation even if a majority of the Parties and Participants agree to assume the debt, liability or obligation of the Authority. Notwithstanding Section 8.4 of this Agreement, this Section 3.3 may not be Approved October 13, 2016 5
amended unless such amendment is approved by the governing board of each Participant.

ARTICLE 4: GOVERNANCE AND INTERNAL ORGANIZATION

4.1 Board of Directors. The governing body of the Authority shall be a Board of Directors (“Board”). The composition of the Board shall be as set forth in Section 4.7. Each Director shall serve at the pleasure of the governing board of the Party or Participant who appointed such Director, and may be removed as Director by such governing board at any time. If at any time a vacancy occurs on the Board, a replacement shall be appointed to fill the position of the previous Director within 90 days of the date that such position becomes vacant.

4.2 Quorum. A majority of the Directors shall constitute a quorum, except that less than a quorum may adjourn from time to time in accordance with law.

4.3 Powers and Functions of the Board. The Board shall exercise general governance and oversight over the business and activities of the Authority, consistent with this Agreement and applicable law. The Board shall provide general policy guidance to the CCA Program. The Board shall be required to approve any of the following actions:
a. The issuance of bonds or any other financing even if program revenues are expected to pay for such financing.
b. The hiring of a Chief Executive Officer and General Counsel. c. The appointment or removal of an officer.
d. The adoption or modification of the annual budget.
e. The adoption of an ordinance.
f. The initiation of litigation where the Authority will be the plaintiff, petitioner, cross complainant or cross petitioner, or intervenor; provided, however, that the Chief Executive Officer or General Counsel, on behalf of the Authority, may intervene in, become a party to, or file comments with respect to any proceeding pending at the California Public Utilities Commission, the Federal Energy Regulatory Commission, or any other administrative agency, without approval of the Board. g. The setting of rates for power sold by the Authority and the setting of charges for any other category of service provided by the Authority, except as provided in Section

4.5.2.1.1. h. Any agreement between the Authority and any Party or Participant if the total amount payable under the agreement and other agreements with the Party or Participant is more than $50,000 in any fiscal year.
i. Termination of the CCA Program.

4.4 Chief Executive Officer. The Board of Directors shall appoint a Chief Executive Officer for the Authority, who shall be responsible for the day-to-day operation and management of the Authority and the CCA Program. The Chief Executive Officer may exercise all powers of the Approved October 13, 2016 6
Authority, except the powers specifically set forth in Section 4.3 or those powers which by law must be exercised by the Board of Directors. The Chief Executive Officer may enter into and execute any Energy Contract, in accordance with criteria and policies established by the Board.

4.5 Commissions, Boards, and Committees. The Board may establish any advisory commissions, boards, and committees as the Board deems appropriate to assist the Board in carrying out its functions and implementing the CCA Program, other energy programs, and the provisions of this Agreement. All advisory commissions, boards, and committees established by the Board shall comply with the requirements of the Ralph M. Brown Act. The Board may establish rules, regulations, policies, bylaws or procedures to govern any such commissions, boards, or committees, and shall determine whether members shall be compensated or entitled to reimbursement for expenses.

4.5.1 Community Advisory Committee. The Board shall establish a Community Advisory Committee consisting of a minimum of seven members and a maximum of eleven members, none of whom may be members of the Board. In appointing members to the Committee, the Board shall use its best efforts to appoint a balanced, diverse group of individuals, a majority of whom represent the interests of customers as ratepayers (both residential and commercial/industrial), and including members having expertise in one or more of the areas of management, administration, finance, or contracts (in either the public or private sector), infrastructure development, renewable power generation, power sales and marketing, energy conservation, public policy development, or public relations.

The Board shall publicize the opportunity to serve on the Community Advisory Committee, and shall appoint members of the Community Advisory Committee from those individuals expressing interest in serving, giving a preference to individuals who are customers of the CCA Program. Members of the Community Advisory Committee shall serve staggered four-year terms as determined by the Board of Directors. A member of the Community Advisory Committee may only be removed by the Board of Directors by a two-thirds vote as provided in Section 4.7.5. Each member of the Community Advisory Committee shall have one vote; a majority of members shall constitute a quorum; and a majority of a quorum is sufficient for committee action.

4.5.2 Duties and Powers of Community Advisory Committee. The Community Advisory Committee shall meet at least six times per calendar year, and shall have the following duties and powers:

4.7.2.1 Review of Budget and Rates. The proposed annual budget of the CCA Program and any rates or charges proposed to be imposed by the Authority for CCA Program power or services shall be submitted to the Community Advisory Committee for review and comment. Following review by the Community Advisory Committee of any such matter, the committee shall recommend to the Board that the matter be approved, approved as amended, or disapproved by the Board. The recommendation of the Community Advisory Committee shall be communicated to the Board and noted on the agenda for the meeting at which the Board considers the matter. The Board may impose a reasonable deadline for action on the Community Advisory Committee as necessary to ensure the timely setting of rates by the Authority.

Approved October 13, 2016 7

4.5.2.1.1 Temporary Rate Changes. Notwithstanding the requirements in Sections

4.3 and 4.5.2.1, the Chief Executive Officer may change any rate for power sold by the Authority or any charge for services provided by the Authority if (a) the need for the change arises from (i) unforeseen circumstances, (ii) a change in rates or charges imposed on the Authority or its customers by PG&E, the CPUC, or any other regulatory agency, or (iii) technical deficiencies or errors in an existing Authority rate or charge; and (b) the Chief Executive Officer determines, following consultation with the Chair of the Board of Directors, that the change is reasonably necessary for budgetary reasons or to keep the Authority’s rates and charges competitive. Changes in rates or charges made by the Chief Executive Officer under this Section shall be brought to the Board of Directors at the next scheduled meeting for consideration and shall expire after 90 days unless ratified by the Board of Directors.

4.5.2.2 Review of Policies and Programs. The Community Advisory Committee may review and may make recommendations with respect to the programs, policies, and operations of the CCA Program to the Chief Executive Officer or to the Board of Directors. The Community Advisory Committee shall have the opportunity to review and comment upon proposals for new programs, policies, or significant operational changes proposed by the Chief Executive Officer for the CCA program. If requested by the Community Advisory Committee, the Chief Executive Officer shall provide the Committee with any information reasonably necessary for the Committee to carry out its duties. Actions of the Community Advisory Committee are advisory only, and Community Advisory Committee action or approval is not a prerequisite to the Board of Directors’ or the Chief Executive Officer’s action on any item.

4.5.2.3 Reports to the Board. The Community Advisory Committee may prepare or cause to be prepared for presentation to the Board any reports, investigations, studies, or analyses relating to the Authority or the CCA Program.

4.5.2.4 Placing Matters on Board’s Agenda. The Community Advisory Committee may place any matter relating to the Authority or the CCA Program on the Board’s agenda for consideration and possible action.

4.5.2.5 Support for Community Advisory Committee. The Board shall provide for reasonable and necessary administrative assistance to the Community Advisory Committee. If requested by the Community Advisory Committee, the Chief Executive Officer shall enter into contracts as reasonably necessary to carry out the duties and powers of the Community Advisory Committee; provided, however, that (a) the amount payable under any contract cannot exceed $20,000 per year, (b) the total amount payable under all contracts cannot exceed $50,000 per year, and (c) the contracts are in a form acceptable to the Authority’s Chief Executive Officer and General Counsel. The Board of Directors may authorize an amount in excess of these expenditure limits if it finds and determines that it is reasonable and necessary to do so for the Community Advisory Committee to perform its obligations.

Approved October 13, 2016 8

4.5.2.6 Chief Executive Officer Reports to Community Advisory Committee. The Chief Executive Officer shall prepare, no later than the 20th day of each first month of each fiscal quarter, a report to the Community Advisory Committee on the operations of the Authority during the preceding fiscal quarter. The report shall contain information regarding the financial performance of the Authority during the preceding quarter, the number of accounts served, the amount of power delivered, and a narrative description of energy efficiency, energy conservation, renewable power generation, and other programs carried out by the Authority.

4.5.2.7 Other Delegated Powers. The Board of Directors may delegate such other and further powers and duties to the Community Advisory Committee as it shall determine in its sole discretion.

4.5.2.8 Existing Committees Dissolved. Effective as of the date this Third Amended and Restated Agreement is approved, the Ratepayer Advisory Committee and the Business Operations Committee are dissolved.

4.6 Director Compensation. Directors shall serve without compensation from the Authority.

However, Directors may be compensated by their respective appointing authorities. The Board, however, may adopt by resolution a policy relating to the reimbursement by the Authority of expenses incurred by Directors.

4.7 Board of Directors Composition. The Board of Directors shall consist of one appointee from each Participant located within the boundaries of the County of Sonoma, and one joint appointee from the County of Sonoma and the Sonoma County Water Agency. If the Board of Directors approves any other municipality or county as a Participant pursuant to Section 3.1, the Board of Directors shall determine whether such municipality or county (or any combination thereof) may appoint an additional member to the Board of Directors. Each appointee must be an elected member of the governing board of his or her appointing body. Each Party or Participant appointing a member to the Board of Directors may also appoint an alternate to serve in the absence of its Director. Alternates must be either an elected member of the governing board of his or her appointing body, or an employee of the jurisdiction appointing them.

The voting shares of Directors and approval requirements for actions of the Board shall be as follows:

4.7.1. Voting Shares.

Each Director shall have a voting share as determined by the following formula: (Annual Energy Use/Total Annual Energy) multiplied by 100, where (a) “Annual Energy Use” means the annual electricity usage, expressed in kWh, of accounts within a Party’s or Participant’s respective jurisdiction that are served by the Authority; and
(b) “Total Annual Energy” means the sum of all Annual Energy Use, expressed in kWh, of accounts within the jurisdictions of those Parties and Participants who have appointed a director to the Board of Directors.

Approved October 13, 2016 9
(c) The combined voting share of all Directors representing the County of Sonoma and the Sonoma County Water Agency shall be based upon the annual electricity usage within the unincorporated area of Sonoma County.

4.7.2. Exhibit Showing Voting Shares. The voting shares of each member of the Board of Directors are set forth in Exhibit C. Exhibit C shall be revised no less than annually as necessary to account for changes in the number of Parties or Participants appointing members to the Board of Directors, and changes in the Parties’ and Participants’ Annual Energy Use.

4.7.3. Approval Requirements Relating to CCA Program. Except as provided in Sections 4.7.4 and 4.7.5 below, action of the Board shall require the affirmative vote of a majority of Directors present at the meeting.

4.7.4. Option for Approval by Voting Shares. Notwithstanding Section 4.7.3, any Director present at a meeting may demand that approval of any matter related to the CCA Program be determined on the basis of voting shares and by the affirmative vote of a majority of Directors present at the meeting. If a Director makes such a demand with respect to approval of any such matter, then approval of such matter shall require the affirmative vote of a majority of Directors present at the meeting and the affirmative vote of Directors having a majority of voting shares of the Directors present at the meeting, as determined by Section 4.7.1 except as provided in Section 4.7.5.

4.7.5. Special Voting Requirements for Certain Matters.

A. Two-Thirds and Weighted Voting Approval Requirements Relating to Sections 4.5.1, 7.2, and 8.4. Action of the Board on the matters set forth in Section 4.5.1 (removal of member of Community Advisory Committee), Section 7.2 (involuntary termination of a Party or Participant), or Section 8.4 (amendment of this Agreement) shall require the affirmative vote of at least two-thirds of Directors; provided, however, that (a) notwithstanding the foregoing, any Director present at the meeting may demand that the vote be determined on the basis of voting shares and by the affirmative vote of Directors, and if a Director makes such a demand, then approval shall require the affirmative vote of at least two-thirds of Directors and the affirmative vote of Directors having at least two-thirds of the voting shares, as determined by Section 4.7.1; (b) when a Director has demanded that the vote be determined on the basis of voting shares and by the affirmative vote of Directors, if any individual Party or Participant’s voting share exceeds 33 and the Director(s) for that Party or Participant votes in the negative or abstains or is absent from the meeting, then at least one other Director representing a different Party or Participant shall be required to vote in the negative, or the matter shall be deemed approved; and (c) for votes to involuntarily terminate a Party or Participant under Section 7.2, the Director(s) for the Party or Participant subject to involuntary termination may not vote, and the number of Directors constituting two-thirds of all Directors, and weighted vote of each Party or Participant, shall be recalculated as if the Party or Participant subject to possible termination were not a Party or Participant.

B. Seventy Five Percent Special Voting Requirements for Eminent Domain and Participant Contributions or Pledge of Assets.

Approved October 13, 2016 10
(i) A decision to exercise the power of eminent domain on behalf of the Authority to acquire any property interest other than an easement, right-of-way, or temporary construction easement shall require a vote of at least 75% of all Directors. (ii) The imposition on any Party or Participant of any obligation to make contributions or pledge assets as a condition of continued participation in the CCA Program shall require a vote of at least 75% of all Directors and the approval of the governing boards of the Parties and Participants who are being asked to make such contribution or pledge.
(iii) Notwithstanding the foregoing, any Director present at the meeting may demand that a vote under subsections (i) or (ii) be determined on the basis of voting shares and by the affirmative vote of Directors, and if a Director makes such a demand, then approval shall require the affirmative vote of at least 75% of Directors and the affirmative vote of Directors having at least 75% of the voting shares, as determined by Section 4.7.1, and when a Director has demanded that the vote be determined on the basis of voting shares and by the affirmative vote of Directors, if any individual Party or Participant’s voting share exceeds 25% and the Director(s) for that Party or Participant votes in the negative or abstains or is absent from the meeting, then at least one other Director representing a different Party or Participant shall be required to vote in the negative, or the matter shall be deemed approved. For purposes of this section, “imposition on any Party or Participant of any obligation to make contributions or pledge assets as a condition of continued participation in the CCA Program” does not include any liabilities or obligations of a withdrawing or terminated party imposed under Section

7.3. 4.8 Meetings and Special Meetings of the Board. The Board shall hold at least four regular meetings per year, but the Board may provide for the holding of regular meetings at more frequent intervals. The date, hour and place of each regular meeting shall be fixed by resolution or ordinance of the Board. Regular meetings may be adjourned to another meeting time. Special meetings of the Board may be called in accordance with the provisions of California Government Code Section 54956. Directors may participate in meetings telephonically, with full voting rights, only to the extent permitted by law. All meetings of the Board, the Community Advisory Committee, or the governing body of any subsidiary entity or independent corporation established by the Authority shall be conducted in accordance with the provisions of the Ralph M. Brown Act (California Government Code Sections 54950 et seq.).

4.9 Selection of Board Officers.

4.9.1 Chair and Vice Chair. The Directors shall select, from among themselves, a Chair, who shall be the presiding officer of all Board meetings, and a Vice Chair, who shall serve in the absence of the Chair. The term of office of the Chair and Vice Chair shall continue for one year, but there shall be no limit on the number of terms held by either the Chair or Vice Chair. The office of either the Chair or Vice Chair shall be declared vacant and a new selection shall be made if: (a) the person serving dies, resigns, or the Party that the person represents removes the person as its representative on the Board or (b) the Party that he or she represents withdraws from the Authority pursuant to the provisions of this Agreement.

Approved October 13, 2016 11

4.9.2 Secretary. The Board shall appoint a Secretary, who need not be a member of the Board, who shall be responsible for keeping the minutes of all meetings of the Board and all other official records of the Authority.

4.9.3 Treasurer and Auditor. The Sonoma County Auditor-Controller-Treasurer-Tax Collector shall act as the Treasurer and the Auditor for the Authority. Unless otherwise exempted from such requirement, the Authority shall cause an independent audit to be made by a certified public accountant, or public accountant, in compliance with Section 6505 of the Act. The Treasurer shall act as the depositary of the Authority and have custody of all the money of the Authority, from whatever source, and as such, shall have all of the duties and responsibilities specified in Section 6505.5 of the Act. The Treasurer shall report directly to the Board and shall comply with the requirements of treasurers of incorporated municipalities. The Board may transfer the responsibilities of Treasurer to any person or entity as the law may provide at the time. The duties and obligations of the Treasurer are further specified in Article 6.

4.10 Administrative Services Provider. The Board may appoint one or more administrative services providers to serve as the Authority’s agent for planning, implementing, operating and administering the CCA Program, and any other program approved by the Board, in accordance with the provisions of a written agreement between the Authority and the appointed administrative services provider or providers (an “Administrative Services Agreement”). The appointed administrative services provider may be one of the Parties. An Administrative Services Agreement shall set forth the terms and conditions by which the appointed administrative services provider shall perform or cause to be performed all tasks necessary for planning, implementing, operating and administering the CCA Program and other approved programs. The Administrative Services Agreement shall set forth the term of the Agreement and the circumstances under which the Administrative Services Agreement may be terminated by the Authority. This section shall not in any way be construed to limit the discretion of the Authority to hire its own employees to administer the CCA Program or any other program.

ARTICLE 5 IMPLEMENTATION ACTION AND AUTHORITY DOCUMENTS

5.1 Preliminary Implementation of the CCA Program.

5.1.1 Enabling Ordinance. Except as otherwise provided by Section 3.1, each Party shall adopt an ordinance in accordance with Public Utilities Code Section 366.2(c)(12) for the purpose of specifying that the Party intends to implement a CCA Program by and through its participation in the Authority.

5.1.2 Implementation Plan. The Authority shall cause to be prepared an Implementation Plan meeting the requirements of Public Utilities Code Section 366.2 and any applicable Public Utilities Commission regulations as soon after the Effective Date as reasonably practicable. The Implementation Plan shall not be filed with the Public Utilities Commission until it is approved by the Board in the manner provided by Section 4.7.3.

5.1.3 Termination of CCA Program. Nothing contained in this Article or this Agreement shall be construed to limit the discretion of the Authority to terminate the implementation or operation of the CCA Program at any time in accordance with any Approved October 13, 2016 12
applicable requirements of state law.

5.2 Authority Documents. The Parties acknowledge and agree that the affairs of the Authority will be implemented through various documents duly adopted by the Board through Board resolution. The Parties agree to abide by and comply with the terms and conditions of all such documents that may be adopted by the Board, subject to the Parties’ right to withdraw from the Authority as described in Article 7.

ARTICLE 6 FINANCIAL PROVISIONS

6.1 Fiscal Year. The Authority’s fiscal year shall be 12 months commencing July 1 and ending June 30. The fiscal year may be changed by Board resolution.

6.2 Depository.

6.2.1 All funds of the Authority shall be held in separate accounts in the name of the Authority and not commingled with funds of any Party or Participant or any other person or entity.

6.2.2 All funds of the Authority shall be strictly and separately accounted for, and regular reports shall be rendered of all receipts and disbursements, at least quarterly during the fiscal year. The books and records of the Authority shall be open to inspection by the Parties and Participants at all reasonable times. The Board shall contract with a certified public accountant or public accountant to make an annual audit of the accounts and records of the Authority, which shall be conducted in accordance with the requirements of Section 6505 of the Act.

6.2.3 All expenditures shall be made in accordance with the approved budget and upon the approval of any officer so authorized by the Board in accordance with its Operating Rules and Regulations. The Treasurer shall draw checks or warrants or make payments by other means for claims or disbursements not within an applicable budget only upon the prior approval of the Board.

6.3 Budget and Recovery of Costs.

6.3.1 Budget. The annual budget shall be approved by the Board. The Board may revise the budget from time to time as may be reasonably necessary to address contingencies and unexpected expenses.

6.3.2 CCA Program Costs. The Parties desire that all costs incurred by the Authority that are directly or indirectly attributable to the provision of electric, conservation, efficiency, incentives, financing, or other services provided under the CCA Program, including but limited to the establishment and maintenance of various reserves and performance funds and administrative, accounting, legal, consulting, and other similar costs, shall be recovered through charges to CCA customers receiving such electric services, or from revenues from grants or other third-party sources.

ARTICLE 7: WITHDRAWAL AND TERMINATION

7.1 Withdrawal.

Approved October 13, 2016 13

7.1.1 Right to Withdraw. A Party or Participant may withdraw its participation in the CCA Program, effective as of the beginning of the Authority’s fiscal year, by giving no less than 6 months advance written notice of its election to do so, which notice shall be given to the Authority and each Party and Participant Withdrawal of a Party or Participant shall require an affirmative vote of its governing board.

7.1.2 Right to Withdraw After Amendment. Notwithstanding Section 7.1.1, a Party or Participant may withdraw its membership in the Authority following an amendment to this Agreement adopted by the Board which the Party or Participant’s Director(s) voted against provided such notice is given in writing within thirty (30) days following the date of the vote. Withdrawal of a Party or Participant shall require an affirmative vote of its governing board and shall not be subject to the six month advance notice provided in Section 7.1.1. In the event of such withdrawal, the Party or Participant shall be subject to the provisions of Section 7.3.

7.1.3 Continuing Liability; Further Assurances. A Party or Participant that withdraws its participation in the CCA Program may be subject to certain continuing liabilities, as described in Section 7.3. The withdrawing Party or Participant and the Authority shall execute and deliver all further instruments and documents, and take any further action that may be reasonably necessary, as determined by the Board, to effectuate the orderly withdrawal of such Party or Participant from participation in the CCA Program.

7.2 Involuntary Termination of a Party or Participant. Participation of a Party or Participant in the CCA program may be terminated for material non-compliance with provisions of this Agreement or any other agreement relating to the Party’s or Additional Participant’s participation in the CCA Program upon a vote of Board members as provided in Section 4.7.5.

Prior to any vote to terminate participation with respect to a Party or Participant, written notice of the proposed termination and the reason(s) for such termination shall be delivered to the Party or Participant whose termination is proposed at least 30 days prior to the regular Board meeting at which such matter shall first be discussed as an agenda item. The written notice of proposed termination shall specify the particular provisions of this Agreement or other agreement that the Party or Participant has allegedly violated. The Party or Participant subject to possible termination shall have the opportunity at the next regular Board meeting to respond to any reasons and allegations that may be cited as a basis for termination prior to a vote regarding termination. A Party or Participant that has had its participation in the CCA Program terminated may be subject to certain continuing liabilities, as described in Section 7.3.

7.3 Continuing Liability; Refund. Upon a withdrawal or involuntary termination of a Party or Participant, the Party or Participant shall remain responsible for any claims, demands, damages, or liabilities arising from the Party or Participant’s membership or participation in the CCA Program through the date of its withdrawal or involuntary termination, it being agreed that the Party or Participant shall not be responsible for any liabilities arising after the date of the Party or Participant’s withdrawal or involuntary termination. Claims, demands, damages, or liabilities for which a withdrawing or terminated Party or Participant may remain liable include, but are not limited to, losses from the resale of power contracted for by the Authority to serve the Party or Participant’s load. With respect to such liability, upon notice by a Participant that it wishes to withdraw from the program, the Authority shall notify the Party or Participant of the minimum waiting period under which the Participant would have no costs for withdrawal if the Participant Approved October 13, 2016 14
agrees to stay in the CCA Program for such period. The waiting period will be set to the minimum duration such that there are no costs transferred to remaining ratepayers. If the Party or Participant elects to withdraw before the end of the minimum waiting period, the charge for exiting shall be set at a dollar amount that would offset actual costs to the remaining ratepayers, and may not include punitive charges that exceed actual costs. In addition, such Party or Participant also shall be responsible for any costs or obligations associated with the Party or Participant’s participation in any program in accordance with the provisions of any agreements relating to such program provided such costs or obligations were incurred prior to the withdrawal of the Party or Participant. The Authority may withhold funds otherwise owing to the Party or Participant or may require the Party or Participant to deposit sufficient funds with the Authority, as reasonably determined by the Authority and approved by a vote of the Board of Directors, to cover the Party’s or Participant’s liability for the costs described above. Any amount of the Party’s or Participant’s funds held on deposit with the Authority above that which is required to pay any liabilities or obligations shall be returned to the Party or Participant. The liability of any Party or Participant under this section 7.3 is subject and subordinate to the provisions of Sections

2.2 and 3.3, and nothing in this section 7.3 shall reduce, impair, or eliminate any immunity from liability provided by Sections 2.2 or 3.3.

7.4 Mutual Termination. This Agreement may be terminated by mutual agreement of all the Parties; provided, however, the foregoing shall not be construed as limiting the rights of a Participant to withdraw its participation in the CCA Program, as described in Section 7.1.

7.5 Disposition of Property upon Termination of Authority. Upon termination of this Agreement, any surplus money or assets in possession of the Authority for use under this Agreement, after payment of all liabilities, costs, expenses, and charges incurred under this Agreement and under any program documents, shall be returned to the then-existing Parties and Participants in proportion to the contributions made by each.

7.6 Negotiations with Participants. If the Parties wish to terminate this Agreement, or if the Parties elect to withdraw from the CCA Program following an amendment to this Agreement as provided in Section 7.1.2, but two or more Participants wish to continue to participate in the CCA Program, the Parties will negotiate in good faith with such Participants to allow the Participants to become parties to this Agreement or to effect a transfer of CCA Program operations to another entity.

ARTICLE 8 MISCELLANEOUS PROVISIONS

8.1 Dispute Resolution. The Parties, Participants, and the Authority shall make reasonable efforts to settle all disputes arising out of or in connection with this Agreement. Should such efforts to settle a dispute, after reasonable efforts, fail, the dispute shall be settled by binding arbitration in accordance with policies and procedures established by the Board.

8.2 Liability of Directors, Officers, and Employees. The Directors, officers, and employees of the Authority shall use ordinary care and reasonable diligence in the exercise of their powers and in the performance of their duties pursuant to this Agreement. No current or former Director, officer, or employee will be responsible for any act or omission by another Director, officer, or employee. The Authority shall defend, indemnify and hold harmless the individual current and former Directors, officers, and employees for any acts or omissions in the scope of their Approved October 13, 2016 15
employment or duties in the manner provided by Government Code Sections 995 et seq. Nothing in this section shall be construed to limit the defenses available under the law, to the Parties, the Participants, the Authority, or its Directors, officers, or employees.

8.3 Indemnification of Parties and Participants. The Authority shall acquire such insurance coverage as is necessary to protect the interests of the Authority, the Parties, the Participants, and the public. The Authority shall defend, indemnify, and hold harmless the Parties and Participants, and each of their respective Board or Council members, officers, agents and employees, from any and all claims, losses, damages, costs, injuries, and liabilities of every kind arising directly or indirectly from the conduct, activities, operations, acts, and omissions of the Authority under this Agreement.

8.4 Amendment of this Agreement. This Agreement may not be amended except by a written amendment approved by a vote of Board members as provided in Section 4.7.5. The Authority shall provide written notice to all Parties and Participants of amendments to this Agreement, including the effective date of such amendments, at least 30 days prior to the date upon which the Board votes on such amendments.

8.5 Assignment. Except as otherwise expressly provided in this Agreement, the rights and duties of the Parties or Participants may not be assigned or delegated without the advance written consent of all of the other Parties and Participants, and any attempt to assign or delegate such rights or duties in contravention of this Section 8.5 shall be null and void. This Agreement shall inure to the benefit of, and be binding upon, the successors and assigns of the Parties and Participants. This Section 8.5 does not prohibit a Party or Participant from entering into an independent agreement with another agency, person, or entity regarding the financing of that Party’s or Participant’s contributions to the Authority, or the disposition of proceeds which that Party or Participant receives under this Agreement, so long as such independent agreement does not affect, or purport to affect, the rights and duties of the Authority or the Parties or Participants under this Agreement.

8.6 Severability. If one or more clauses, sentences, paragraphs or provisions of this Agreement shall be held to be unlawful, invalid or unenforceable, it is hereby agreed by the Parties, that the remainder of the Agreement shall not be affected thereby. Such clauses, sentences, paragraphs or provision shall be deemed reformed so as to be lawful, valid and enforced to the maximum extent possible.

8.7 Further Assurances. Each Party agrees to execute and deliver all further instruments and documents, and take any further action that may be reasonably necessary, to effectuate the purposes and intent of this Agreement.

8.8 Execution by Counterparts. This Agreement may be executed in any number of counterparts, and upon execution by all Parties, each executed counterpart shall have the same force and effect as an original instrument and as if all Parties had signed the same instrument.

Any signature page of this Agreement may be detached from any counterpart of this Agreement without impairing the legal effect of any signatures thereon, and may be attached to another counterpart of this Agreement identical in form hereto but having attached to it one or more signature pages.

Approved October 13, 2016 16

8.9 Parties to be Served Notice. Any notice authorized or required to be given pursuant to this Agreement shall be validly given if served in writing either personally, by deposit in the United States mail, first class postage prepaid with return receipt requested, or by a recognized courier service. Notices given (a) personally or by courier service shall be conclusively deemed received at the time of delivery and receipt and (b) by mail shall be conclusively deemed given 48 hours after the deposit thereof (excluding Saturdays, Sundays and holidays) if the sender receives the return receipt. All notices shall be addressed to the office of the clerk or secretary of the Authority or Party, as the case may be, or such other person designated in writing by the Authority or Party. Notices given to one Party shall be copied to all other Parties. Notices given to the Authority shall be copied to all Parties and Participants.

Approved October 13, 2016 17
Exhibit A
Definitions
“AB 117” means Assembly Bill 117 (Stat. 2002, ch. 838, codified at Public Utilities Code Section 366.2), which created CCA.
“Act” means the Joint Exercise of Powers Act of the State of California (Government Code Section 6500 et seq.)
“Administrative Services Agreement” means an agreement or agreements entered into after the Effective Date by the Authority with an entity that will perform tasks necessary for planning, implementing, operating and administering the CCA Program or any other energy programs adopted by the Authority.
“Agreement” means this Joint Powers Agreement.
“Annual Energy Use” has the meaning given in Section 4.7.2. “Authority” means the Sonoma Clean Power Authority.
“Authority Document(s)” means document(s) duly adopted by the Board by resolution or motion implementing the powers, functions, and activities of the Authority, including but not limited to the Operating Rules and Regulations, the annual budget, and plans and policies. “Board” means the Board of Directors of the Authority.
“CCA” or “Community Choice Aggregation” means an electric service option available to cities, counties, and the Sonoma County Water Agency pursuant to Public Utilities Code Section 366.2. “CCA Program” means the Authority’s program relating to CCA that is principally described in Sections 2.3, 2.4, and 5.1.
“Director” means a member of the Board of Directors representing a Party or an Additional Participant.
“Effective Date” means December 4, 2012, the date on which this Agreement became effective and the Sonoma Clean Power Authority began to exist as a separate public agency. “Energy Contract” means any agreement for the purchase or sale of electrical energy or any related attributes, including but not limited to capacity, resource adequacy, transmission or congestion rights, demand response products, or environmental attributes. “Implementation Plan” means the plan generally described in Section 5.1.2 of this Agreement that is required under Public Utilities Code Section 366.2 to be filed with the California Public Utilities Commission for the purpose of describing a proposed CCA Program. “Initial Costs” means all costs incurred by the Authority relating to the establishment and initial operation of the Authority, such as the hiring of a Chief Executive Officer and any administrative staff, any required accounting, administrative, technical, or legal services in support of the Authority’s initial activities or in support of the negotiation, preparation, and approval of one or Approved October 13, 2016 18
more Administrative Services Provider Agreements and Program Agreement 1. Administrative and operational costs incurred after the approval of Program Agreement 1 shall not be considered Initial Costs.
“Operating Rules and Regulations” means the rules, regulations, policies, bylaws and procedures governing the operation of the Authority.
“Participant” or “Additional Participant” means any incorporate municipality or county electing to participate in the CCA Program.
“Parties” means, collectively, the County of Sonoma and the Sonoma County Water Agency. “Party” means the County of Sonoma or the Sonoma County Water Agency. “Total Annual Energy” has the meaning given in Section 4.7.2.

Approved October 13, 2016 19
Exhibit B
List of Parties and Participants
Parties: County of Sonoma, Sonoma County Water Agency
Participants: Town of Windsor; City of Cotati; City of Sebastopol; City of Sonoma; City of Santa Rosa; City of Petaluma; City of Rohnert Park; City of Cloverdale Exhibits C
Annual Energy Use and Voting Shares
Party/Participant Annual Energy
Use (kWh)
Voting
Shares
City of Cloverdale 37,537,769 1
City of Cotati 33,051,134 1
City of Petaluma 356,047,033 13
City of Rohnert Park 206,884,365 8
City of Santa Rosa 895,830,982 33
City of Sebastopol 45,381,441 2
City of Sonoma 69,071,078 3
County of Sonoma 949,469,086 35
Town of Windsor 101,875,412 4
Total 2,695,148,300 100
ATTACHMENT 4
2025 Lake County Expansion Feasibility Study
Feasibility Study
Sonoma Clean Power Expansion to Unincorporated Lake
County, the City of Clearlake, and the City of Lakeport May 2025
Version 1.1
2 v1.1
Table of Contents
Chapter 1. Executive Summary....................................................................................... 3 Chapter 2. Background ................................................................................................... 4 Community Choice Aggregation (CCA) ....................................................................... 4 SCP Cannot Promise Lower Rates.............................................................................. 5 Lake County Interest in CCA Service .......................................................................... 6 Sonoma Clean Power Policy for New Customer Communities.................................... 7 Chapter 3. Lake County Electricity Demand.................................................................... 9 Lake County Load ....................................................................................................... 9 Comparison to Existing Customers of Sonoma Clean Power.................................... 10 Chapter 4. Sonoma Clean Power Electric Service ........................................................ 12 Products & Resource Portfolio................................................................................... 12 Credit & Financial Resources .................................................................................... 14 Customer Programs and Customer Service .............................................................. 15 Chapter 5. Economic Evaluation ................................................................................... 16 Power Costs .............................................................................................................. 16 Administrative Costs.................................................................................................. 18 Uncollectible Revenue............................................................................................... 19 Revenue Requirement............................................................................................... 19 Startup Costs............................................................................................................. 20 Customer Type and Usage Pattern Impacts to Unit Revenue ................................... 20 PG&E Generation Rates, PCIA, and Rate Competitiveness ..................................... 21 Sensitivity Analysis .................................................................................................... 23 Reserves and Rate Stabilization Fund Considerations.............................................. 25 Chapter 6. Local Resource Development Opportunities ............................................... 26 Geothermal Opportunity Zone (GeoZone)................................................................. 26 Other Clean Energy Opportunities............................................................................. 28 Chapter 7. Additional Benefits ....................................................................................... 28 Chapter 8. Risks............................................................................................................ 29 Chapter 9. Implementation ............................................................................................ 31 Enrollment Process ................................................................................................... 31 Governance............................................................................................................... 32 3 v1.1
Chapter 1. Executive Summary
Staff recommend the SCP Board consider extending service to all of Lake County.

This feasibility study provides a comprehensive review of the requirements to expand Sonoma Clean Power (SCP) service to unincorporated Lake County, the City of Clearlake, and the City of Lakeport (referred to as “Lake County”). The study characterizes the load of Lake County and performs an economic evaluation to assess the financial feasibility of expansion. This report also provides background on Community Choice Aggregation (CCA) and SCP’s current electric service, and discusses resource development opportunities, benefits of expansion, potential risks, and outlines implementation steps. The main findings of this study and considerations are as follows:
• Expanding service to all of Lake County appears to be financially beneficial to both Lake County customers and existing SCP customers in a majority of years. • Key considerations for the SCP Board of Directors are:
o Should an offer of service to Lake County and the Cities of Clearlake and Lakeport be made at this time?
o Does the Board agree to staff’s recommendation for starting service between April and June 2027?
o Does the Board wish to use the same practice as in Mendocino County by offering one Board seat to the County of Lake Supervisors and one shared seat for the two incorporated cities of Clearlake and Lakeport? o Does the Board wish to stress the importance of the GeoZone and seek to confirm that Lake County is aligned and wishes to join the GeoZone? • Expansion to Lake County appears to be well aligned with the criteria established in SCP’s Policy for New Customer Communities D.4.
• SCP’s current portfolio of long-term renewable contracts is sufficient to accommodate expansion to Lake County without requiring additional long-term procurement to maintain compliance.
• Startup costs for an expansion to Lake County are estimated to be $578,000, which forecasts indicate would be recouped through rates in the first year of service.
• In the base market scenario used for evaluation, Lake County customers see total bill savings of 4% or more, however, it is important to note that there is a clear possibility that total bills will be higher with SCP some of the time due to changing PG&E fees outside SCP’s control and energy market conditions. 4 v1.1
• An expansion to Lake County will increase SCP’s target for reserves by $42.7 million (using 2030 costs), which would have the effect of reducing SCP’s ability to provide savings until that higher balance is achieved. The time estimated to accumulate the additional reserves while sustaining competitive rates is difficult to estimate, but likely could be completed by 2032.
• Lake County’s participation in the GeoZone is mutually beneficial and it is strongly recommended that Lake County join the GeoZone concurrently with SCP’s electric service.
• Expansion to Lake County offers additional benefits such as more cost-effective building electrification opportunities, increased portfolio flexibility, improved advocacy, and additional phone and web support for customers in Lake County. • Risks that should be considered before proceeding with an expansion include the impacts of a jurisdiction withdrawing from SCP service, high customer opt-outs, possible impacts to SCP’s credit rating, and the inability to guarantee rates that are lower than PG&E.
• The feasibility plan outlines steps leading up to an April to June 2027 start date, including approvals from SCP’s Board and Lake County jurisdictions, as well as filings with the CPUC, customer noticing, and outreach.

Chapter 2. Background
Community Choice Aggregation (CCA)
CCAs were created in response to California’s
2000-2001 energy crisis through Assembly Bill
117 in 2002. CCAs enable local governments to
purchase electricity generation for their residents
and businesses that is delivered to customers by
an investor-owned utility (IOU). In Northern
California, the IOU is Pacific Gas & Electric
(PG&E). The first CCA, Marin Clean Energy
(now MCE), started service in 2010. Sonoma
Clean Power (SCP) started service as the state’s
second CCA in 2014. There are now 25 CCAs in
the state serving over 14 million customers and
participation continues to grow. Figure 1 shows
the expected footprint of CCA service in
California by 2027.

Figure 1. Map of areas expected to be served by
CCAs by 2027.
5 v1.1
CCAs are governed by elected officials from participating jurisdictions and operate as government agencies that are not-for-profit and return all revenues to ratepayers in the form of competitive electric rates and customer education and incentives.

Figure 2. Roles of SCP and PG&E in delivering electric service to customers.

The role of CCAs, including SCP, is primarily to buy or build power generation resources on behalf of all customers, while PG&E continues to maintain and operate all of the poles, wires and substations of the grid. Figure 2 illustrates the roles of SCP and PG&E in delivering electric service to customers.

When a CCA is formed or expands, new customers must be automatically enrolled as a CCA customer unless they choose to opt-out and continue relying on PG&E to procure electricity for their home or business. If a customer opts-out after 60 days of starting service with a CCA, they must remain on PG&E service for one year before being eligible to enroll in CCA service.

SCP Cannot Promise Lower Rates
CCA customers receive a consolidated bill from PG&E including generation charges from the CCA as well as transmission and distribution charges from PG&E. The bill for CCA customers includes a charge called the Power Charge Indifference Adjustment (PCIA) that covers costs for energy that was procured by the IOU prior to a customer’s departure from IOU service. The PCIA changes annually depending on market conditions - if the IOU’s energy portfolio that was procured for CCA customers performs well (due to high market prices), the PCIA is lower; if the portfolio performs poorly, the PCIA is higher. This fee ensures that PG&E cannot lose any money as a result of CCA formation. To limit opt-outs, CCAs generally seek to offer rates that are competitive and lead to total bills (including the impact of PCIA) that are at or below the total bill for IOU customers – as often as possible. Figure 3 shows SCP’s history of total bill savings relative to PG&E, which shows a strong historical record of providing savings to 6 v1.1
customers. Importantly, SCP cannot guarantee future rate savings—and did go through a period of two years where its customers paid higher bills than opt-out customers.

Figure 3. Historical bill comparison between SCP and PG&E.

CCA customers retain eligibility for ratepayer-funded programs through the California Public Utilities Commission (CPUC), such as income qualified assistance programs, energy efficiency rebates, and medical baseline discounts. CCA customers also gain access to incremental programs offered by the CCA which are not otherwise available from PG&E. SCP offers incremental equipment rebates, incentives for participation in its demand response program, and a variety of other programs for energy efficiency and electrification. SCP, like other CCAs, also offers a net energy metering (NEM) and solar billing plan (SBP) program that compensates solar customers.

In addition to CCAs, California law also created a program called Direct Access (DA) that allows customers to purchase electricity from a competitive third-party. DA has an annual load cap that is currently fully subscribed. The vast majority of DA customers are non-residential. There are currently around 70 meters in Lake County with service from DA, representing 7.4 gigawatt-hours (GWh) of annual load (which is less than 2% of Lake County’s total). Unlike PG&E customers, DA customers will not be automatically enrolled in CCA service. Although if SCP expands to Lake County DA customers would have the option of CCA service, this study evaluates service to only non-DA customers although inclusion of DA customers would have negligeable impact.

Lake County Interest in CCA Service
The Lake County Board of Supervisors unanimously passed Ordinance 3206 on June 23, 2015, to authorize implementation of a CCA program, with the goal of reducing energy costs for Lake County residents. Lake County explored various options to 7 v1.1
implement CCA service on its own at the time, but ultimately did not proceed. Lake County re-evaluated CCA service in 2019, when it requested SCP to study the feasibility of expanding service to Lake County. SCP’s study, which was released in March 2020, found that it would be unable to offer competitive service to Lake County residents at the time due to the expected cost of PG&E’s PCIA fee on Lake County relative to the PCIA fee on SCP’s existing customers.

Market and regulatory dynamics following the feasibility study in 2020 have greatly improved the economic prospects for new CCA service. As described in detail in Chapter 5, PG&E’s PCIA fee is now lower for new CCA jurisdictions relative to the PCIA for SCP’s customers. These conditions led to Sonoma Clean Power reengaging with Lake County, the City of Clearlake, and City of Lakeport in early 2025. After preliminary discussions with SCP, the city managers of City of Clearlake and City of Lakeport made a written request to the Sonoma Clean Power Board of Directors to complete a new feasibility study. Likewise, the Lake County Board of Supervisors authorized staff to submit a written request for a feasibility study after discussion during the April 15, 2025 meeting. The Sonoma Clean Power Board of Directors directed SCP staff to respond to Lake County interest by completing the requested feasibility study.

In the 2025 discussions between SCP and the Lake County jurisdictions, SCP staff captured several factors that are driving interest in CCA expansion: the opportunity to reduce energy costs for Lake County residents, increased economic development opportunities (through geothermal and other types of local project development), improved customer service, and better representation in energy-related advocacy.

Sonoma Clean Power Policy for New Customer Communities
In December 2015, the Sonoma Clean Power Board of Directors adopted Policy D.4 that guides the procedure for evaluating and facilitating expansion to new jurisdictions.

The policy includes a set of criteria that must be met to proceed with an expansion that are summarized in Table 1 below, along with SCP staff’s recommended determination and if applicable, a reference to the applicable chapter of this study.

In addition to the evaluation criteria, Policy D-4 also establishes the series of steps SCP shall follow in expanding participation to a new region. After completing a feasibility study and presenting the results to the candidate community and SCP Board of Directors, the current SCP Board members have a 60-day period to evaluate expansion and discuss the opportunity with their own city councils or Board of Supervisors. The SCP Board of Directors will then vote on whether to extend a formal offer for service.

The timing of this process, along with the required steps to formally enroll Lake County in SCP service, are further detailed in Chapter 9.
8 v1.1
Table 1. Policy D-4 New Community Evaluation Criteria
Criteria SCP Staff’s Recommended Determination
Community is close to SCP service
territory to make meeting attendance
and community engagement practical
(Criteria 1).

Pass – Lake County jurisdictions directly border SCP
territory. The commute to Santa Rosa is not quick but is comparable to many parts of SCP’s existing territory in Mendocino County.

Community agrees to abide by SCP
Joint Powers Agreement (JPA),
policies, and conditions of service
(Criteria 2).

TBD - This is subject to the careful review and determination by Lake County and the Cities of Clearlake and Lakeport.

Service to new region will decrease
greenhouse gas emissions and be
consistent with purpose of promoting
renewable energy, energy efficiency,
and conservation (Criteria 3a and 3c).

Pass – Expansion would provide additional room for
expansion in SCP’s renewable portfolio, improve
opportunities for local clean energy development, and enable more cost-competitive electrification. See Chapters 6 and 7.

Service to new region will not increase
cost or financial risks to existing
customers (Criteria 3b).

Pass – Expansion to Lake County would leverage
efficiencies of scale and increases flexibility in SCP’s power portfolio with the effect of generally decreasing cost and risk to existing customers. The additional load would come with additional procurement obligations and a potential increase in meeting those additional obligations. However, the overall expectation is that, on average, costs would remain or
decline due to serving Lake County. See Chapter 5 and 7.

Significant political and public
alignment between new community
and proposed participants and addition
of new community will increase voice
of SCP in relevant venues (Criteria 4
and 5).

TBD – Staff note that Lake County shares many of the same regional priorities as Sonoma and Mendocino County: wildfire mitigation, energy affordability, water scarcity, sustainability of small businesses and the agricultural industry. California’s 4th Congressional District and the 2nd State Senate District span both SCP and Lake County. Expansion would add the 4th
State Assembly District to SCP’s territory, currently
represented by Assembly Majority Leader Aguiar-Curry.

Ultimately, however, this determination must be made by the SCP Board of Directors, the County of Lake Board of
Supervisors, and the City Councils of Clearlake and
Lakeport.

Addition of the new community will not
harm SCP’s autonomy (Criteria 6).

Pass – Expansion to Lake County is expected to involve two new seats on the current eleven-seat Board of Directors (one for the County and one shared seat between the two
incorporated cities). Staff do not see how the scale of the expansion would threaten the autonomy of SCP’s power
sources and priorities. However, staff urge SCP and all of the jurisdictions in Lake County to consider the political alignment of objectives carefully.

Addition of the new community will not
harm the quality of service or give rise
to operational risks (Criteria 7).

Pass – The economic study includes budgeted costs to
expand staff and SCP’s investments to serve Lake County without impacting existing customers. See Chapter 5.
9 v1.1
Chapter 3. Lake County Electricity Demand
Lake County Load
In order to facilitate a feasibility study, Sonoma Clean Power obtained customer data and hourly load for all customers in Lake County from PG&E for the years 2022, 2023, and 2024. Like Sonoma Clean Power’s current load, Lake County’s load is fairly stable and most year-to-year fluctuations are driven by weather. For the purposes of this study, staff have decided to use Lake County’s 2024 load and customer composition as the basis for evaluating feasibility—even though some modest growth is expected due to electrification. Table 2 below shows a breakdown of meter count and annual load by jurisdiction and residential and non-residential meters using the 2024 data. This table excludes the DA meters discussed in Chapter 2 which would not be automatically enrolled but could opt-in to CCA service in the future.

Table 2. Lake County Load and Customer Breakdown by Jurisdiction City of Clearlake City of Lakeport Unincorporated
Lake County Total
Residential
Meters 7,216 2,418 22,361 31,995
Non-residential
Meters 610 671 3,067 4,348
Total Meters 7,826 3,089 25.428 36,343
Residential
Annual Load 61.5 GWh 18.6 GWh 174.8 GWh 254.8 GWh
Non-residential
Annual Load 23.2 GWh 17.6 GWh 95.9 GWh 136.7 GWh
Total Annual
Load 84.7 GWh 36.2 GWh 270.7 GWh 391.5 GWh
Lake County’s load has two peak seasons—with increased usage in the summer due to hot temperatures driving air conditioning demand and is similarly high in the winter due to electric heating needs. Figure 4 shows the monthly load for Lake County. Lake County does not have access to PG&E’s natural gas system and accordingly has more electric heating1. Due to more extreme summer heat, air conditioning ownership is also more prevalent in Lake County, which increases summer energy needs. 1 Data from the American Community Survey from the U.S. Census Bureau estimates 42.7% of Lake County residences use electricity as their main heating source, compared to 24.4% in Sonoma and

19.1% in Mendocino counties.
10 v1.1
Figure 4. Monthly load for Lake County.

The average hourly load profile for Lake County is shown in Figure 5. Hourly load is low in the middle of the day due to generation from behind-the-meter solar. Customer data suggests 15% of Lake County’s meters have Net Energy Metering (NEM) solar.

Increased load in the evening is driven by cooling and heating needs as residents return home. Figure 5 shows an average across the year, but for context Lake County’s load varied in 2024 from as low as 7 MW midday on a sunny day in May to 96 MW on a hot July evening.

Figure 5. Hourly load profile for Lake County.

Comparison to Existing Customers of Sonoma Clean Power
The addition of Lake County could increase the number of meters served by Sonoma Clean Power by 15.6% and Sonoma Clean Power’s load by 18.5%. Table 3 shows a breakdown of how Lake County’s meter count and load compares to Sonoma Clean Power. The annual electric usage per residential meter is over 56% higher in Lake -
5 10
15 20
25 30
35 40
45 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
GWhr
Monthly Lake County Load
0 10
20 30
40 50
60 70
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 MW
Hour Ending
Average Hourly Lake County Load
Residential Non-residential
11 v1.1
County (8.0 MWh/year in Lake County versus 5.1 MWh in SCP)—which leads to a disproportionate increase in load compared to meter count. Lake County’s meter count and load is also more residential (less commercial) than SCP. The figures for Lake County in Table 3 include 100% of eligible customers and do not reflect the effect of customers who choose to opt-out—which are assumed to be 10% in the evaluation in Chapter 5. The conclusions of this analysis are not sensitive to the actual opt-out rate.

Table 3. Lake County Load vs. Sonoma Clean Power
Sonoma Clean
Power Lake County Total % Potential Increase
Residential
Meters 200,824 31,995 232,819 15.9%
Non-residential
Meters 31,862 4,348 36,210 13.6%
Total Meters 232,686 36,343 269,029 15.6%
Residential
Annual Load 1,022.6 GWh 254.8 GWh 1,277.5 GWh 24.9%
Non-residential
Annual Load 1,090.0 GWh 136.7 GWh 1,226.6 GWh 12.5%
Total Annual
Load 2,112.6 GWh 391.5 GWh 2,504.1 GWh 18.5%
Figure 6 shows the monthly load per meter for Lake County compared to SCP. Like Lake County, SCP has high usage in the summer and winter—although the Lake County fluctuations are amplified. Figure 7 shows an average hourly load comparison.

The hourly load shapes are also very similar given similar penetrations of NEM solar and increased energy needs in the evening. In looking at 2024 data, the hourly load for Sonoma Clean Power and Lake County together would have fluctuated between 99 MW to 567 MW. The peak load of 567 MW is 17.5% higher than Sonoma Clean Power’s standalone peak of 483 MW—and would occur at the same hour on a hot July evening.

Understanding the impact of Lake County to SCP’s load shape and peak are critical to evaluating the revenue requirement that is detailed in Chapter 5. 12 v1.1
Figure 6. Monthly load comparison for Sonoma Clean Power and Lake County.

Figure 7. Hourly load comparison for Sonoma Clean Power and Lake County.

Chapter 4. Sonoma Clean Power Electric Service
Products & Resource Portfolio
SCP offers customers a choice between two products: CleanStart and EverGreen.

CleanStart is SCP’s standard offering and the default product for new customers.

Power from CleanStart is sourced from renewable and carbon-free resources across 0 200
400
600
800
1000
1200
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
MWh/meter
Monthly Load per Meter
Sonoma Clean Power Lake County
0 0.2

0.4 0.6

0.8 1

1.2 1.4

1.6 1.8
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Hourly Load per Meter (kW)
Hour Ending
Average Hourly Load per Meter
Sonoma Clean Power Lake County
13 v1.1
the Western Interconnection. A small portion, approximately ten to twelve percent, of CleanStart is provided by unspecified resources—which are primarily natural gas.

EverGreen is SCP’s premium product that customers can opt-in to for an additional cost of 2.5 cents per kilowatt-hour. This premium translates to $17 extra per month for a typical Lake County household. EverGreen is completely sourced from local renewable resources within SCP’s territory. Unlike products offered by other power providers, EverGreen is unique in that it is backed by resources that deliver clean energy for every hour—rather than relying on natural gas power to back up variable resources like solar and wind power. If Lake County were to join SCP, resources within Lake County would become eligible to provide EverGreen-eligible generation.

SCP contracts for power from long-term power purchase agreements (PPAs), shortterm contracts that give SCP claim to the bundled renewable or carbon-free attribute of energy, and purchases from the spot market. Table 4 is a list of long-term PPAs expected to be in SCP’s portfolio in 2027. If Lake County were to join SCP, incremental energy needs would be first filled with new short-term contracts and spot market purchases, but long-term SCP would seek additional PPAs to optimize costs.

Importantly, the resources in Table 4 provide 1,271 GWh of renewable annual energy, which is sufficient to meet the long-term contract compliance minimum for Sonoma Clean Power after an expansion to Lake County2.

Table 4. Long-term Power Purchase Agreements
Facility Technology Capacity Annual Energy
Geysers
Sonoma County, CA Geothermal 20 MW3 175.2 GWh
Mustang
Kings County, CA Solar 70 MW 156.2 GWh
Golden Hills
Alameda County, CA Wind 46 MW 124.6 GWh
Proxima
Stanislaus County, CA Solar 70 MW 169.1 GWh
2 State law requires 65% of SCP’s renewable energy for meeting compliance requirements is sourced from long-term contracts. The renewable compliance requirement for renewable energy maxes out at 60% in 2030—which means SCP would need 39% of its total energy in long-term renewable contracts. 3 Contract includes 9 MW in 2027 that ramps-up to 20 MW in 2028-2037; table shows ramp-up values 14 v1.1
Facility Technology Capacity Annual Energy
Azalea
Kern County, CA Solar 60 MW 150.9 GWh
SunZia
New Mexico Wind 100 MW 328.1 GWh
Ormat Portfolio
Imperial County, CA &
Nevada
Geothermal 14 MW 122.6 GWh
Fish Lake
Nevada Geothermal 1.5 MW 13.3 GWh
Redemeyer
Mendocino County, CA Solar 4 MW 10.1 GWh
ProFIT
Sonoma & Mendocino
County, CA
Solar 6 MW
(6 projects x 1 MW) 13.8 GWh
Montgomery Creek
Shasta County, CA Small Hydro 2.6 MW 7.4 GWh
Total: 1, 271 GWh
Credit & Financial Resources
In 2021, SCP received an ‘A’ issuer credit rating from S&P Global Ratings that was reaffirmed in 2024. SCP’s investor-grade credit rating is important in negotiating favorable power contract terms and reflects the agency’s fiscal strength. SCP has no outstanding debt. In 2024, on behalf of SCP, the California Community Choice Financing Authority (CCCFA) issued $775.6 million in pre-pay bonds that provide SCP’s customers with significant reductions in energy costs. Notably, those bonds do not appear on SCP’s financial statements or impact SCP’s borrowing capacity.

SCP’s latest financial statement from February 2025 shows $373 million in total assets.

SCP is targeting an end-of-year reserves balance of about $268 million which reaches the Board of Directors’ target reserves of 365 days of annual budgeted operating expenses. SCP’s financial policy dictates a minimum reserves balance of 180 days of operating expenses. SCP has funded a rate stabilization fund with a current balance of $56 million, which makes up a portion of total reserves. The rate stabilization fund is meant to provide flexibility in setting competitive rates in future years with a high PG&E PCIA fee. Conditions warranting the use of the rate stabilization fund are expected in 2026, but not necessarily in 2027 when service to Lake County would begin, though 15 v1.1
forecasting the PCIA fee is difficult due to frequent regulatory changes and energy market price movement. The fee on SCP customers has varied by over $100 million in a single year, so the scale of this fee is important to consider.

Customer Programs and Customer Service
SCP offers programs and incentives to customers and the community to improve energy affordability, encourage electrification, and increase energy efficiency. These programs are incremental to programs offered by PG&E. A list of currently offered programs is included below. Note that these are subject to change at any time, including before Lake County would begin service in 2027, but are indicative of the types and scale of programs to expect.
• GridSavvy Rewards: GridSavvy is a demand response program that invites customers to sign-up to receive alerts for energy conservation or connect a smart thermostat or EV charger to be dispatched during energy-savings events in the summer. Customers receive a sign-up cash bonus and a modest payment for their performance in reducing energy during periods of grid stress. • Electric Appliance Rebates: SCP offers rebates that can be added to state and local incentives for heat pump HVAC, induction cooking, and heat pump water heaters. The rebates are higher for low-income customers - providing up to $10,000 toward equipment and installation.
• Energy Savings Box: A free energy savings box packed with easy-to-use tools to conserve energy including things like LED lightbulbs, smart plugs, and weather stripping. The box contains over $100 of useful equipment and shipped directly to customers.
• Commercial Energy Assistance Program: An internal energy expert will identify energy savings opportunities for interested businesses and conduct an onsite visit with a detailed follow-up report.
• Non-profit EV Incentives: Up to $22,500 for non-profits to assist non-profits with the purchase of an electric vehicle.
• Solar: SCP compensates customers with solar by applying credits toward a future bill or as part of an annual cash-out.

SCP staffs a customer call center and the Sonoma Clean Power Customer Center in downtown Santa Rosa to assist customers with utility bills, electrification questions, customer programs, and other needs. SCP staff can assist residential and commercial customers with selecting an optimal rate plan and have a strong track record of identifying opportunities for customer cost savings.
16 v1.1
SCP also supports the community through partnerships and funding. As examples, SCP currently partners with the Career Technical Education Foundation and the LIME Foundation for training and curriculum for careers in clean energy and sustainability.

SCP also offers scholarships at local colleges, sponsors many key community events, and raises donations for food banks in Sonoma and Mendocino Counties.

Chapter 5. Economic Evaluation
In assessing the viability of SCP expansion to Lake County, results must both provide Lake County a reasonable expectation of competitive electric rates and the SCP Board of Directors with confidence that the expansion is not disadvantageous to SCP’s current customers. The power market is very dynamic and conditions are certain to vary from the forecasts used as the basis for this evaluation. Accordingly, this chapter also includes several sensitivities to test the robustness of the results.

Power Costs
In assessing the cost of power for Lake County, this feasibility study assumes a 90% opt-in rate - which is slightly higher than SCP’s current opt-in rate of 87% but a reasonable expectation given the experience of recent CCA expansion elsewhere in the state4. This feasibility study also assumes a start date of April 2027, which appears optimal from a monthly review of cost and compatibility with SCP’s portfolio but may occur as late as June. Costs are forecasted through 2030, when the price forecast SCP uses begins to stabilize. The projections for 2030 are a reasonable proxy for future years. SCP’s direct costs of power for Lake County are driven by four components: the cost of wholesale power, the cost of energy attributes, grid charges from the California Independent System Operator (CAISO), and the cost of resource adequacy (RA).

These are considered together with PG&E’s charges for transmission, distribution and numerous fees and surcharges, including the PCIA in evaluating total bill impacts.

The cost of wholesale power for Lake County is highly dependent on its hourly load profile. Power costs directly correlate to the availability of renewable and hydro resources. Power is often cheaper in the spring and midday and more expensive in the evening and winter months when solar, wind and battery storage are less available. To assess the cost of power for Lake County, SCP developed an hourly load profile using smart meter data from 2024 and leveraged future hourly price forecasts available through its Ascend PowerSIMM platform as of April 12, 2025. The feasibility study assumes that the early years of power for Lake County will be procured entirely from the spot market, although in practice SCP would likely seek to optimize costs through 4 Pioneer Community Energy achieved 99% opt-in rates in their 2024 expansion to Grass Valley and Nevada City. Peninsula Clean Energy achieved 89% opt-in rate in their 2022 expansion to Los Banos. 17 v1.1
signing additional long-term PPAs. SCP needs to procure sufficient power to cover metered sales plus losses on the distribution system, which adds an additional 6%.

Table 5 shows the unit cost, volume, and total dollars needed to provide wholesale energy to Lake County with a 90% participation rate (equal to 10% opt out). Note that the per unit results are not very sensitive to the actual participation rate.

In expanding to Lake County, SCP would need to maintain compliance with statemandated renewable energy requirements while also seeking to maintain its Boardadopted voluntary environmental performance targets. As with wholesale power, SCP would seek to optimize the cost of its portfolio long-term through signing PPAs with resources that provide renewable or carbon-free energy. In the short-term, the volume of renewables needed for Lake County is estimated by applying the state’s compliance minimum by year against the metered load. The volume of carbon-free energy needed to meet SCP’s voluntary targets is calculated to reach a portfolio that is 93.5% renewable or carbon-free5. The required procurement of resources for Lake County is reduced by allocations SCP would expect to receive for Lake County’s portion of carbon-free power from the Diablo Canyon Nuclear Power Plant and PG&E’s hydropower fleet that is included in PCIA. Table 5 shows the resulting need for renewable and carbon-free to serve Lake County, along with the expected procurement cost based on current market prices.

CAISO charges SCP grid charges in addition to wholesale power costs to cover its costs of operation. These grid charges are expected to grow proportional to load. For this evaluation, SCP is assuming grid charges add an additional $1.50 per MWh of wholesale load.

SCP is required to procure resource adequacy (RA) for its load. RA is a contract with power plants to provide standby capacity to respond to peak grid conditions and is California’s regulatory solution for ensuring system reliability. Recent revisions to RA rules require SCP to prove it has a resource fleet, battery storage, and short-term RA contracts sufficient to provide capacity across 24 hours for a peak load day each month.

This new structure is known as “slice of day” and differs from the past approach of planning for a single peak hour. The incremental RA cost for serving Lake County is related to how Lake County’s load profile interfaces with SCP’s existing resource fleet and load shape. The cost of RA included in the table below is based on an assessment of how much additional RA, either firm capacity from natural gas plants or battery storage capacity, SCP needs to maintain compliance with its RA obligation when adding Lake County’s load to its portfolio.
5 A 93.5% renewable or carbon-free annual metric is consistent with a recent staff recommendation to adopt an 85% hourly renewable or carbon-free target for 2026 and beyond 18 v1.1
The total power cost for Lake County is forecasted to grow from $25.6 million in the 9 months of participation and grow to $40.2 million per year in 2030, which represents around a 14% increase relative to SCP’s power cost forecast in outer years without Lake County participation. This increase is lower than the anticipated 15.4% growth in sales, which importantly indicates that Lake County participation is expected to reduce power costs borne by SCP’s current customers.

Table 5. Power Cost Forecast
2027 (Apr-Dec) 2028 2029 2030
90% Opt-in Metered Sales MWh 255,342 351,182 351,182 351,182 Wholesale Power $/MWh 59.01 63.36 70.59 77.65
Wholesale MWh 270,663 372,253 372,253 372,253
Wholesale $ thousands 15,970 23,585 26,278 28,906
Renewable Need % 52.0% 54.7% 57.3% 60.0%
Carbon Free Allocation % 18.6% 18.3% 17.3% 13.0%
Carbon Free Need % 22.9% 20.5% 18.8% 20.5%
Renewable Need MWh 132,778 191,991 201,333 210,709
Carbon Free Need MWh 58,513 72,008 66,141 71,845
Clean Energy $ thousands 4,490 5,136 5,217 5,507
CAISO Grid Charges $ thousands 402 553 553 553
Resource Adequacy $ thousands 4,823 5,274 5,274 5,274
Total Power Cost $ thousands 25,690 34,554 37,327 40,246 Total Power Cost ¢/kWh 10.06 9.84 10.63 11.46
Administrative Costs
Adding Lake County to SCP would introduce some efficiencies of scale, but there are costs associated with data management and PG&E service fees that directly scale with meter count. SCP also anticipates growing customer service staff to maintain its high level of service, and expanding the budget for marketing, communications, and programs incentives for Lake County. Program participation for Lake County is forecasted to grow to the level of adoption SCP currently sees in Mendocino County.

Overall, expansion to Lake County is expected to increase SCP’s administrative costs by around 4%--which is lower than the anticipated 15.4% growth in sales. A breakdown of the administrative cost forecast is included in Table 6. 19 v1.1
Table 6. Administrative Cost Forecast, $ Thousands
Category 2027 (Apr-Dec) 2028 2029 2030
Data Management 337.5 450.0 450.0 450.0
PG&E Service Fees 11.3 15.0 15.0 15.0
Personnel 250.0 270.0 280.0 290.0
Marketing & Communications 570.0 400.0 410.0 420.0
Customer Service 50.0 50.0 50.0 50.0
Programs Incentives 120.0 240.0 330.0 350.0
Total Administrative Cost 1,338.8 1,425.0 1,535.0 1,575.0 Total Administrative Cost ¢/kWh 0.52 0.41 0.44 0.45
Uncollectible Revenue
A consideration in determining the revenue requirement for a utility is the amount of revenue that is uncollectible. SCP’s collectible rate on its current customers is 98.6%, which means rates need to be set to recover 101.4% of projected costs. Lake County is expected to have a lower collectible rate due to lower average household incomes than SCP territory. Whereas 16.5% of SCP meters are enrolled in the California Alternative Rates for Energy (CARE) income-assistance program, 43.1% of Lake County meters are enrolled. This feasibility study applies SCP’s observed CARE-specific collection rate of 96.6% and non-CARE collection rate of 98.7% using the 43.1% weighting of CARE meters in Lake County to estimate an overall 97.8% collection rate. In evaluating the revenue requirement for Lake County, rates are therefore set at 102.2% of projected costs.

Revenue Requirement
Table 7 below incorporates the incremental load, power costs, administrative costs, and uncollectible rates associated with an expansion to Lake County alongside the SCP financials for the status quo to evaluate the impact of expansion to SCP’s revenue requirement. Importantly, the results show that due to efficiencies of scale and compatibility with SCP’s portfolio, an expansion is expected to provide a reduction in the per-kilowatt-hour revenue requirement for SCP. These results suggest that an expansion to Lake County would not create an additional financial burden on existing SCP ratepayers and are an indication of the generation rates SCP could offer given the assumed market conditions. The revenue requirement does not include any contributions to reserves, which is discussed in a later section. 20 v1.1
Table 7. Revenue Requirement Comparison, ¢/kWh
Scope 2027 (Apr-Dec) 2028 2029 2030
SCP (Status Quo) 11.79 12.55 13.12 13.62
SCP + Lake County Expansion 11.66 12.27 12.88 13.43
Change -0.13 -0.28 -0.24 -0.19
Startup Costs
The power and administrative costs above reflect ongoing expenses pertinent to evaluating the long-term viability of a Lake County expansion. There are also one-time costs that SCP would incur in expanding to Lake County. These costs cover enrollment notices, staff outreach, travel expenses, preparation of this feasibility report, and marketing. The SCP Board will want to take these costs into consideration while establishing its offer for service to Lake County. For context, the revenue requirement reduction detailed in Table 7 generates $238,000 of reduced costs for SCP ratepayers per month in 2027, implying that the payout for SCP’s investments in startup costs will likely occur within three months.

Table 8. Startup Costs
Category Startup Cost, $ Thousands
Feasibility Report Staff Time 15
Implementation Plan Update 10
Outreach Staff Time 236
Enrollment Notices 150
Travel Expenses 24
Marketing & Communication 143
Total Startup Costs 578
Customer Type and Usage Pattern Impacts to Unit Revenue SCP currently sets rates by making adjustments to PG&E’s rate schedules—all of which fluctuate with season and customer type and many that also vary based on time of day.

Because Lake County’s load profile and customer mix is different than SCP’s existing customers, a potentially important consideration is whether the different customer mix will impact revenue. To approximate the impact of these dynamics, the average rate for a given month, hour, and residential or non-residential customer was determined from SCP’s current rates. These implied rates were then applied to the hourly residential and non-residential load profiles for Lake County. The results imply Lake County would 21 v1.1
provide 0.6% more revenue per kilowatt-hour. The results of this analysis were close enough to treat the revenue contribution of Lake County and SCP the same when assessing the revenue contribution of an overall generation rate.

PG&E Generation Rates, PCIA, and Rate Competitiveness
A key priority for Lake County in exploring SCP service is the potential for delivering lower cost electricity to its residents. To evaluate the potential for rate savings compared to PG&E service, the revenue requirement estimated for the expansion in Table 7 should compare favorably to generation rates expected to be offered by PG&E, net of the effects of PG&E’s PCIA fee. Both PG&E’s competing generation rate and PCIA depend on market conditions. If market prices of energy are lower, PG&E is able to reduce its generation rates and yet the PCIA paid by CCA customers increases due to poorer market performance of the portfolio PG&E procured for departing customers.

Although a CCA’s revenue requirement also decreases in a low-price market, the lower PG&E generation rate and higher PCIA make it difficult to maintain cost competitiveness. Conversely, in a high-price market scenario PG&E’s generation rates increase to cover costs and the PCIA is reduced, making CCA competitiveness generally easier.

PCIA rates vary by the date customers depart PG&E service (called “vintage” by PG&E). Most SCP customers are on the 2014 vintage with a PCIA based on the portfolio of resources PG&E procured before 2014. If Lake County were to join SCP service in April through June 2027, they would be assigned vintage year 20266. Their 2026 vintage portfolio would include the resources in SCP’s PCIA portfolio but also resources procured between 2014 and 2026. The resources PG&E has procured in that timeframe have by and large been more cost-competitive than their older vintage portfolio—which has had the impact of significantly reducing PG&E’s PCIA fee for newer vintages of CCA customers. To offer savings, SCP must offer rates that are at or below the PG&E generation rate minus the PCIA - a term referred to as “competitive differential”. Table 9 shows the 2025 generation rate paid by PG&E customers, PCIA credit, and resulting competitive differential for three different vintages to illustrate how PCIA has reduced over time. The table shows that 2025 vintage customers pay 3.25 cents less per kWh for PCIA than SCP’s 2014 vintage customers. At SCP’s current generation rate of 11.5 cents per kWh, SCP’s current customers enjoy a discount of 2.4 cents per kWh versus service with PG&E. At that same rate, as an example, a 2025 vintage customer would enjoy a discount of 5.7 cents per kWh. A 2.4 cent per kWh discount is a 16% decrease from PG&E for generation and reduces total bills (which 6 PG&E assigns vintage based on a fiscal year that runs from July 1st through June 30th. April 2027 through June 2027 is thus in the 2026 vintage year.
22 v1.1
include 20 cents per kWh of additional costs paid to PG&E for transmission and distribution) around 7%.

Table 9. PG&E Gen Rate, PCIA, and Competitive Differential by Vintage, ¢/kWh 2014 Vintage 2020 Vintage 2025 Vintage
2025 PG&E Generation Rate 14.99
2025 PCIA 1.06 0.31 -2.19
2025 Competitive Differential 13.93 14.68 17.17
PG&E’s generation rate, PCIA, and resulting headroom are expected to change before 2027. The PCIA is currently lower due to high-price market conditions in 2024 that were used as the basis for setting 2025 rates. Market prices have since fallen and the forecast model SCP used to estimate the power costs for this feasibility study provide conditions in 2027 for a lower PG&E generation rate and higher PCIA. SCP has access to a model that can provide an estimate for future generation rates and PCIA by vintage using market assumptions and has leveraged that model to predict competitive differential for the same market conditions underpinning the power cost estimates.

However, it is important to note that actual PG&E rates and fees have historically varied significantly from estimates – both estimates made by SCP and estimates made by PG&E. Table 10 shows the anticipated PG&E competitive differential for a 2026 vintage (Lake County) and 2014 vintage (SCP) compared to the revenue requirement estimate for an expansion from Table 7.

Table 10. Competitive Differential Forecast vs. Revenue Requirement, ¢/kWh 2027 (Apr-Dec) 2028 2029 2030
SCP Expansion Revenue Requirement 11.66 12.27 12.88 13.43 PG&E 2026 Vintage Competitive
Differential (Lake County) 16.35 15.55 15.22 14.89
PG&E 2014 Vintage Competitive
Differential (SCP) 12.95 12.69 12.74 12.78
SCP currently sets the same generation rates for its customers, regardless of PCIA vintage. If SCP continues that practice in expanding to Lake County and sets rates at its revenue requirement, Table 10 indicates Lake County with its 2026 vintage PCIA would enjoy higher savings than SCP customers in Mendocino and Sonoma Counties (1.46 cents per kWh to 4.69 cents per kWh of savings relative to PG&E service, which 23 v1.1
represents 9.8% to 28.7% savings on generation or 4.2% to 12.9% savings on a total bill basis). In this same scenario, current SCP customers would be seeing comparatively smaller discounts (or a slight premium) due to their 2014 vintage, but with increased savings relative to the status quo without expansion. In 2027, SCP would need to add some costs to its revenue requirement to build reserves up to the new higher target balance beyond the amounts reflected in Table 10.

Sensitivity Analysis
Changes in regulations are a key uncertainty in predicting the future but are difficult to model and forecast. As a result, staff have completed this analysis assuming the existing regulatory conditions. In contrast, power market conditions are the other key uncertainty in determining the economic feasibility of expanding SCP service to Lake County and are possible to model. Power prices not only drive the costs for serving Lake County’s load, but also directly influence PG&E’s generation rate, PCIA, and competitive differential that determines whether SCP service offers cost savings. In order to understand the robustness of the feasibility study’s findings, scenarios have been evaluated for both a high and low market price scenario. Figure 8 shows the power price assumptions used in the low and high price scenarios compared to the base case described above.

Figure 8. Power price assumptions for low and high price sensitivities vs. base case.

Table 11 shows the expected total power costs in the low price and high price scenarios compared to the base case. Whereas the base case represents a scenario with an average power cost of 10.5 cents per kWh, the low case averages 8.45 cents per kWh and the high scenario averages 14.23 cents per kWh. Because this feasibility study assumes power for the expansion to Lake County will be first procured on the spot market, the overall power costs are very sensitive to market price assumptions. 0 20
40 60
80 100
120
2027 2028 2029 2030
North Path 15 Hub Price
($/MWh)
Annual Hub Price vs. Sensitivity Scenario
Base Case Low Price Market High Price Market
24 v1.1
Table 11. Power Costs for Lake County by Sensitivity Scenario, ¢/kWh Scenario 2027 (Apr-Dec) 2028 2029 2030
Base Case 10.06 9.84 10.63 11.46
Low Price Market 9.01 8.17 8.49 8.11
High Price Market 13.36 12.89 15.28 15.39
In order to understand whether the changes in power costs impact the determination that a Lake County expansion lowers the revenue requirement to existing SCP ratepayers, SCP’s existing load profile and power portfolio were tested using the same scenarios with and without a Lake County expansion. The results of this analysis are shown in Table 12.

Table 12. Revenue Requirement Comparison by Sensitivity Scenario, ¢/kWh Scenario Scope 2027 (Apr-Dec) 2028 2029 2030
Low Price Market
SCP (Status Quo) 11.29 11.61 11.89 11.77
SCP + Lake County
Expansion 11.08 11.23 11.53 11.37
Change -0.21 -0.38 -0.37 -0.40
High Price Market
SCP (Status Quo) 13.65 14.69 16.26 16.27
SCP + Lake County
Expansion 13.72 14.54 16.24 16.26
Change +0.07 -0.15 -0.02 -0.01
Unlike Lake County’s power costs, a large portion of SCP’s power is contracted through long-term power purchase agreements at fixed prices. These contracts reduce the sensitivity of SCP’s revenue requirement to variations in market price. Accordingly, the revenue requirement benefits for an expansion to Lake County are amplified in the low market scenario compared to base case results in Table 7 because an expanded portfolio can realize more benefits from reduced power costs. Conversely, the revenue requirement benefits in a high price scenario are muted because SCP’s portfolio becomes more exposed to high market prices with an expansion. However, even in the high price scenario, the revenue requirement with an expansion is either similar or lower than the status quo—indicating that expansion is likely advantageous to SCP across a range of market conditions.
25 v1.1
The low price and high price market scenarios were also tested in the PCIA and competitive differential model—as different market conditions will impact the competitiveness of the rates SCP is able to offer. Table 13 shows the revenue requirement results from Table 12 alongside the PG&E competitive differential model outputs for the low and high price scenarios. In the low price scenario, the competitive differential is reduced due to higher PCIA and reduced PG&E generation rates. The results show that the revenue requirement reductions, however, are likely sufficient to continue providing discounts to the 2026 vintage for Lake County. The low scenario for 2014 vintage customers shows reduced discounts in 2027 and 2028 and increased premiums in 2029 and 2030—but the amplified revenue requirements benefits in the low scenario improve their outcome relative to service without Lake County. In the high market scenario, the differential increases disproportionately to the revenue, allowing greater potential for savings for the 2026 vintage. These results demonstrate that the feasibility study’s finding that SCP could likely deliver competitive rates for Lake County is applicable across a range of market conditions.

Table 13. Competitive Differential Forecast by Scenario, ¢/kWh Scenario Scope 2027 (Apr-Dec) 2028 2029 2030
Low Price
Market
SCP Expansion Revenue
Requirement 11.08 11.23 11.53 11.37
2026 Vintage Competitive
Differential (Lake County) 15.31 14.16 13.39 12.04
2014 Vintage Competitive
Differential (SCP) 11.92 11.31 10.92 9.95
High Price
Market
SCP Expansion Revenue
Requirement 13.72 14.54 16.24 16.26
2026 Vintage Competitive
Differential (Lake County) 19.25 18.21 19.35 18.18
2014 Vintage Competitive
Differential (SCP) 15.84 15.33 16.85 16.05
Reserves and Rate Stabilization Fund Considerations
The results above assume the rates are set at SCP’s revenue requirement and no contribution is made to reserves or a rate stabilization fund7. In practice, SCP will need to budget for contributions to reserves and the rate stabilization fund in years with sufficient competitive differential. Conversely, in years where the revenue requirement is above the competitive differential, SCP would likely draw from its stabilization fund or reserves to provide competitive electric bills to customers. 7 SCP’s rate stabilization fund is a subset of SCP’s reserves entirely made up of deferred revenue. In contrast, the rest of SCP’s reserves are comprised of revenue that was recognized. 26 v1.1
Expanding to Lake County equates to a $21.1 million increase in SCP’s minimum reserves requirement using 2030 costs (the reserves minimum is 180 days of operating costs). Given its current assets and budget for the next year, SCP expects to have a sufficient reserves balance to accommodate the increased requirement without supplemental revenue requirements before or after the start of service.

SCP’s current financial policy sets a target reserves balance of 365 days and stipulates that during periods where SCP is below its target, rates should be set to meet it within 5 years while still protecting customers from unreasonable rates. Adding Lake County increases SCP’s target reserves balance by $42.7 million using 2030 costs. In order to build $42.7 million in additional reserves by the end of 2032, rates would need to be set at 0.28 cents per kWh above the revenue requirement (on average). Depending on the market scenario, this would likely offset the cost reductions for expanding service projected for existing SCP ratepayers in the short term but still allow for discounts to Lake County customers.

An important consideration in expanding to Lake County is that the reserves and rate stabilization fund built-up from SCP’s existing participants will be spread out over 15.4% more load.

Chapter 6. Local Resource Development Opportunities
Since inception, a core value of SCP has been supporting the construction of local energy resources that provide economic development opportunities to the communities it serves. SCP has contracted with the Geysers, built six 1 MW local solar projects, and is currently building a 4 MW solar with storage project in Mendocino County. SCP has created the Geothermal Opportunity Zone (GeoZone) in partnership with Sonoma and Mendocino counties with the aim of building 600 MW of new geothermal capacity. SCP has also recently created a capital projects department specifically focused on building local energy resources. In expanding to Lake County, SCP may find new opportunities for partnership in resource development and use its leverage as a large power customer and regulatory advocate to steer development towards positive outcomes for the region.

Geothermal Opportunity Zone (GeoZone)
SCP’s GeoZone is structured as a public-private partnership to promote local geothermal development. SCP sees clean firm resources such as geothermal as key components of the future grid. The motivation of GeoZone is to leverage SCP’s community relationships, power offtake, and political and regulatory advocacy to build geothermal capacity that is cost-competitive at scale-up and that generates significant local economic benefits. GeoZone partners commit to offering SCP a first right-ofrefusal on all future capacity—locking-in long-term ratepayer benefits if a scale-up is 27 v1.1
successful.

The Clear Lake Volcanic Field that underlies the Geysers creates a regional temperature anomaly that provides favorable conditions for both conventional geothermal development—such as the existing operation at the Geysers—as well as deployment of next-generation geothermal technologies. Although next-generation technologies such as Enhanced Geothermal Systems (EGS) and advanced closed loop (ACL) are technically viable far beyond
the reaches of existing geothermal
fields, the elevated temperatures in that
area allow for them to be tested at
shallower depths and lower cost. SCP
has identified an “Early Interest Area” in
the GeoZone where elevated
temperatures and transmission
availability are likely to attract near-term
development interest. Figure 9 shows
how SCP expects the “Early Interest
Area” could expand should Lake
County join the GeoZone. Figure 9
also shows the Geothermal Setback
Area where Lake County has passed a
moratorium on geothermal
development that would be left
unchanged.

Adding Lake County to the GeoZone
would be mutually beneficial. By
expanding the total land area of
opportunities, SCP and GeoZone
partners are more likely to identify viable projects. Lake County offers high rock temperatures, lower land costs, and significant transmission infrastructure that are likely to attract development interest. Through participation in the GeoZone, Lake County would have increased influence on guiding project development and selecting project partners and importantly would retain its existing jurisdiction over projects proposed within its borders. It would also benefit from SCP’s investment in community engagement and through long-term cost savings from commercial commitments in the GeoZone cooperation agreements. Although Lake County is likely to see geothermal development regardless of participation in the GeoZone, participation in the GeoZone will attract additional interest from industry—accelerating and increasing the scale of investment.

Figure 9. Early interest area for an expanded GeoZone
with Lake County.
28 v1.1
Given the strategic nature of the GeoZone and potential long-term ratepayer benefits, it is strongly recommended that Lake County join the GeoZone concurrently with SCP’s electric service. The SCP Board may want to establish expectations or a requirement on Lake County’s participation in the GeoZone in its offer for service.

Other Clean Energy Opportunities
Lake County has excellent conditions for clean
energy development beyond geothermal power
as well. In 2024, Calpine installed two utility-scale
battery storage systems totaling 38 MW at the
Geysers. AES is in the early stages of developing
a 70 MW wind project in Morgan Valley (see
Figure 10). Lake County and the Hidden Valley
Lake Community Services District have been
exploring the development of closed-loop pumped
hydropower systems. Lake County has high solar
irradiance, high wind power density, relatively
affordable land, and access to transmission.

Lake County’s participation in SCP would support
clean energy development that maximizes local
benefits. As a potential buyer of local projects,
SCP can increase the importance of local
considerations in siting and constructing projects.

SCP offtake of local projects also allows Lake County residents to directly benefit from electricity generation. SCP is also very active in advocacy at the CPUC, California Energy Commission (CEC), and CAISO and can advocate for infrastructure and grants to support local project development for Lake County. Importantly, SCP’s new capital projects team provides an avenue for SCP to directly invest and build resources in Lake County.

Chapter 7. Additional Benefits
SCP expansion to Lake County offers potential benefits beyond ratepayer savings and increased opportunities for partnership in local resource development. These additional benefits include:
• Cost-effective building electrification: SCP has invested heavily in building programs, incentives, and expertise to promote building electrification. However, electrification in Sonoma and Mendocino Counties is challenging because it is not clearly cost-effective due to the relatively low cost of natural gas compared to Figure 10. Wind power density map for Lake
County with location of Morgan Valley project.
29 v1.1
electricity. Lake County does not have access to natural gas and instead relies on higher-cost propane for heating. SCP thus expects the cost-effectiveness of electrification to be significantly better in Lake County which will result in higher adoption rates and allow faster and larger impact.
• Increased portfolio flexibility: As shown in Table 4, over half of SCP’s existing load is served by long-term contracts, which limit SCP’s flexibility to optimize its portfolio if costs decline or new resources or technologies become available.

Adding additional load increases opportunities for SCP to optimize its portfolio.

Adding load also increases utilization of SCP’s existing resources, including its large battery storage fleet. Although the revenue requirement estimates in Chapter 5 assume spot market purchases for incremental load, SCP will look for new long-term contract opportunities that provide supplemental savings. • Improved advocacy: Adding Lake County would expand SCP’s voice to be representative of energy-related issues across a broader region and a more diverse set of experiences. Partnering with Lake County would give SCP more direct experience in understanding the concerns of tribes, low-income communities, and regions that are net exporters of electricity. Lake County would gain access to SCP’s expertise in engaging in energy-related issues with the CPUC, CEC, CAISO, and PG&E to address local priorities. • Improved customer service: SCP staffs a call center and a Customer Center in Santa Rosa that provides very responsive customer service. SCP is able to answer questions on both its own charges and PG&E bill overall. SCP staff also has a long-track record of delivering savings to customers by identifying optimal rate plans, low cost or no cost tips for energy savings, and information on energy efficient appliances.
• Customer choice: An intrinsic benefit of a jurisdiction participating in CCA service is that it provides customers with a choice for two options for their electric provider, where before they had only PG&E. Providing choice to Lake County gives customers greater control over their electricity sources and costs, and creates competition that encourages better service and lower costs.

Chapter 8. Risks
The economic evaluation and benefits listed in Chapter 6 and Chapter 7 provide support for moving forward with expansion of SCP service to Lake County. However, in evaluating whether to proceed it is important to understand the following risks:
• Financial risk to Lake County jurisdictions: Section 3.3 of the JPA governing SCP stipulates that the debts, liabilities, and obligations of SCP shall not be the 30 v1.1
debts, liabilities, or obligations, of participating jurisdictions. Accordingly, participation in SCP should not have any impact on the credit rating or books of Lake County jurisdictions. This also means that member cities and counties of SCP have absolutely no access to the funds or other assets of SCP. In addition, if a jurisdiction decides to completely withdraw from SCP service, Section 7.3 of the JPA give that jurisdiction a choice: (A) they may withdraw on a date of SCP’s choosing without cost obligation, noting that date may be as far in the future as the length of SCP’s longest energy contract (typically 20 or 25 years); or (B) the withdrawing jurisdiction must pay SCP for the financial liability for costs related to the jurisdiction’s participation in SCP service—including losses from the resale of power contracts entered to serve load (an amount that will generally exceed $40 million for a region the size of Lake County). Given the practical difficulty of withdrawal, Lake County jurisdictions should only consider SCP participation if they intend on making a very long-term commitment that will weather different rate and political environments.
• Customer opt-outs: This study assumes a 90% participation rate. However, given the flexibility allowed to individual customers in switching power providers, the participation rate could be higher or lower. High opt-outs could lead to a situation where SCP has excess energy procured in long-term contracts that is not offset by customer revenues. SCP seeks to mitigate customer opt-out risk by investing heavily in marketing and community engagement leading up to start of service and make procurement decisions for the expansion with the flexibility to adapt to lower or higher opt-out rates.
• SCP credit rating: SCP’s current investor-grade credit rating is based on its financial assets, portfolio position, industry conditions, and the demographics of its customers among other conditions. Although this study demonstrates that expansion is financially prudent, credit rating agencies may see it as adding risk—particularly given the impact to the reserves target and the lower average household income observed in Lake County. SCP will seek to mitigate this issue by socializing the financial merits of the expansion with rating agencies and building up reserves to the new higher target balance.
• PG&E Generation Rates & PCIA: As demonstrated in Chapter 5, the ability of SCP to offer competitive rates is very sensitive to the generation rate and PCIA PG&E charges. SCP’s estimates of PG&E’s rates and fees are based on a model calibrated to long sets of historical data, but regulatory changes or changes in PG&E’s procurement practices could cause future generation rates and PCIA to diverge from SCP’s forecasts in Chapter 5. Although this analysis provides strong evidence that SCP will be able to offer competitive rates to Lake County, discounts cannot be guaranteed.
31 v1.1
• Legislative and regulatory risk: SCP is subject to many different compliance requirements, which can be changed through new legislation or rulemaking.

Compliance requirements can challenge the ability of SCP to compete or can devalue its existing resources. SCP seeks to mitigate this risk by investing heavily in its own legislative and regulatory capacity and working through its trade association CalCCA.

Chapter 9. Implementation
Enrollment Process
The steps for Lake County joining SCP service are established in SCP’s Policy D-4, CPUC Resolution 4907, and guided by best practices by other CCA expansions. The steps in Table 14 below include the activities SCP anticipates in working towards a start of service date between April and June 2027 (exact date to be determined following CPUC approval of an updated Implementation Plan).

Table 14. Enrollment Activities and Expected Timing
Expected Timing Activity
June 2025 Socialize Feasibility Study: Feasibility Study presented to SCP Board and Lake County jurisdictions. Starts 60-day clock for SCP jurisdictions to review.

July 2025 Tribal Engagement: SCP, with support from Lake County, begins engaging Lake County tribes to build awareness of CCA service and address concerns.

August to
September 2025
(depending on
meeting schedule)
SCP Board Invitation: SCP Board of Directors votes on whether to extend a formal offer of service
Lake County Ordinance Approval: Lake County jurisdictions approve resolution requesting SCP membership and ordinance authorizing CCA service through SCP. Note: this requires two consecutive meetings.

October 2025 SCP Resolution: SCP Board of Directors adopts resolution authorizing participation of Lake County jurisdictions.

Drafting: SCP staff write an updated Implementation Plan and circulate to the SCP Community Advisory Committee for review.

November 2025 Implementation Plan: SCP Board certifies the updated Implementation Plan and SCP staff submits updated Implementation Plan to CPUC with Lake County expansion
February 2026 Implementation Plan Certified: CPUC must certify it has received the Implementation Plan within 90 days of filing.
32 v1.1
Expected Timing Activity
April 2026 RA: SCP submits its load forecast for 2027 RA requirements including Lake County.

Sep 2026 Customer Outreach: SCP hires necessary staff and begins community outreach in Lake County in earnest including participation in community events, advertising/marketing, and dedicated townhall meetings.

July 2026 Procurement: SCP is assigned RA obligation for Lake County and begins supplemental procuring resources to serve load in earnest.

February 2027 First Notice: SCP will mail notices to all prospective customers describing terms of service and customer’s opt-out opportunity before service.

March 2027 Second Notice: SCP will mail second notice to all prospective customers describing terms of service and customer’s opt-out opportunity before service.

Between April and
June 2027 (TBD)
Start of Service: PG&E will transfer eligible accounts to SCP service based on billing period.

Governance
SCP is governed by a Board of Directors composed of elected members from participating jurisdictions. The early Board included one appointee from Sonoma County and one from each of the participating municipalities in Sonoma County. When SCP expanded to Mendocino County in 2017, one seat was assigned to Mendocino County and one seat was shared by the three participating cities: Fort Bragg, Point Arena, and Willits. The SCP Board currently has eleven total board members.

Decisions of the Board of Directors are generally made by a majority of directors present at the meeting, but a director can request approval of any matter also require the majority of voting shares. Voting shares are allocated between participants proportional to annual load.

It is the staff’s recommendation that the Board consider following the approach used in expanding to Mendocino County. Adding one seat from Lake County’s Board of Supervisors and a shared seat between the City of Clearlake and City of Lakeport would expand the SCP Board of Directors to thirteen seats. The three Lake County jurisdictions are expected to represent 13.5% of SCP’s load after expansion. Two seats on a 13-member board closely approximates their load share (15.4% vs. 13.5%), which will still be used as the basis for allocating voting shares.

ATTACHMENT 5
Correspondence and Supplemental Information
• SCP Memo to Lake County (October 2, 2025) – Issued following the September 30 Joint Workshop of the Board of Supervisors and the Cities of Clearlake and Lakeport.
• Letter from SCP Chair to the City of Clearlake (October 6, 2025) – Submitted following the Clearlake City Council’s October 2 decision not to join Sonoma Clean Power.
• Letter from Denise Rushing to the Lake County Board of Supervisors (October 9, 2025) – Provides community perspective and commentary regarding Sonoma Clean Power participation.

P.O. Box 1030, Santa Rosa, CA 95402
October 2, 2025
Dear Supervisors and Council Members,
Thank you again for all getting together this past Tuesday to discuss the details of joining SCP. In that meeting, two questions came up that I’d like to further address.

First, a question arose of how Tribes will be consulted before the default for power generation service changes to SCP in 2027. I’m committed to working with the County’s Tribal Liaison to consult with Tribes in 2026, well in advance of service, and to offer the option of proactively opting out their accounts if they choose. These meetings will also give us an opportunity to learn about local Tribes and hopefully find ways to better serve them.

Second, the public comments indicated a concern that SCP has specific geothermal project sites and technologies, but isn’t sharing that information. This is a misunderstanding. The Geothermal Opportunity Zone (or GeoZone) is a process we’ve created to seek out good geothermal power projects with significant public input along the way. SCP does not have any specific projects to propose yet in Lake County, and we commit to refreshing and updating our community development principles for new geothermal with input from Lake County residents as well.

I hope this additional input is helpful as you consider joining SCP.

Sincerely,
Geof Syphers, CEO
From: Geof Syphers
To: Matthew Rothstein; Kevin Ingram
Subject: FW: Thank You and Clarifications Regarding Sonoma Clean Power Date: Monday, October 6, 2025 8:32:01 AM
Attachments: image001.png
Matthew and Kevin,
Below is a letter our Chair sent to the Clearlake Council members. He is asking if you can please share it with your Board and Council.

Thanks.

Geof Syphers

CHIEF EXECUTIVE OFFICER
Direct: (707) 225-1073
Customer Service: 1 (855) 202-2139
sonomacleanpower.org
SCPA is committed to protecting customer privacy. This electronic message transmission (email) contains information from SCPA that may be confidential or privileged. The information is intended to be solely for the use of the individual or entity to whom this email is addressed. If you are not the intended recipient, be aware that any disclosure, copying, distribution, or use of the contents of this information is prohibited. If you have received this email in error, please immediately notify us by telephone (1-855-202-2139) or by electronic mail (sender’s email), and confirm that you have deleted the email and any copies. Learn more at https://sonomacleanpower.org/privacy-policy.

From: Barnacle, Brian <[email protected]>
Date: Friday, October 3, 2025 at 5:46 PM
To: [email protected] <[email protected]>, [email protected] <[email protected]>, [email protected] <[email protected]>, [email protected] <[email protected]>, [email protected] <[email protected]>
Subject: Thank You and Clarifications Regarding Sonoma Clean Power CAUTION: EXTERNAL SENDER!
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Dear Mayor Cremer, Vice Mayor Slooten, and Councilmembers, Thank you for taking the time to consider requesting service from Sonoma Clean Power (SCP). While the outcome wasn't what I hoped for, I know that you did what you believe is best for your constituents. I want to express my sincere appreciation for your consideration. I also want to offer a bit of context and a few clarifications on points that came up, so that you have better information moving forward.

First, some of you raised concerns about Sonoma Clean Power’s GeoZone initiative.

Instead of polluting communities in other parts of the state that abut natural gas fired power plants, SCP's GeoZone initiative is an effort that will invest hundreds of millions of dollars into local communities to generate clean, low-cost, firm electricity for our communities — and bring good-paying construction and operations jobs to our region.

The agency prides itself on being a good community partner. We have been doing outreach about the GeoZone initiative for four years and do not even have a project being permitted, or even site control. Earlier this year, we adopted the strongest procurement standards in the industry to ensure that environmental stewardship, local hiring and community outreach are part of any project we select. Our goal is not just to procure clean energy, but to lift up communities, create good jobs, and be a trusted local partner.

SCP is not the only actor who will be looking to build geothermal in Lake County; the State Department of Water Resources has been directed to procure two gigawatts of geothermal power — the equivalent of 3 geysers — and their process will not have the same community protections that we apply to our own procurement. Joining SCP would give you a prominent voice in how SCP’s GeoZone unfolds, something my board members and I welcomed.

Second, there was concern that this process felt rushed or lacked transparency and community engagement. Over the past few months our CEO has made 17 trips to Lake County—often after hours—to answer questions and provide information to community members, elected officials, and staff. We made the GeoZone part of this discussion because we wanted to be transparent about the breadth of our interests in Lake County —no surprises. I'm grateful to our CEO and the SCP staff who have made the trips; they put a great deal of effort into ensuring there was time and space for dialogue. The reality is that to be considered for service expansion in 2027 by the CPUC we need a decision before our November meeting.

Third, there were comments about us being salesmen. I suppose there is truth to those comments, but to be honest I didn't do the agency justice last night. Serving on the SCP board is an honor and a privilege. We have outstanding leadership and a great culture; Geof has been our CEO since our founding eleven years ago and for a majority of those years we have been voted one of the North Bay's best places to work.

We are financially strong and well run; we achieved our 10-year reserve goals 6+ months early while keeping our rates below PG&E in all but two years. In the last two years, our regulatory advocacy and innovative financing mechanisms have resulted in Sonoma and Mendocino County residents and businesses saving millions of dollars each year; I guarantee you that PG&E does not have people looking at ways to save ratepayers, but we do.

We are active in the community; we participated in over 300 community events last year, fed the poor, sponsored CTE programs and internships, and donated to numerous nonprofits and community events (like the Clear Lake Summer Movie Night!). My fellow board members and I are passionate about the mission and the work of agency; we're proud of our accomplishments and our staff — whose passion and expertise are second to none. So yes, I was selling, but I was also being modest! Finally, I do not think I was clear about the expectations of member agencies and their electeds. We rely on and expect our member agencies and their elected officials to be SCP's main brand ambassadors and champions in the communities they represent.

Joining SCP comes with an obligation to learn the complexities of the energy space so you can educate your constituents on what is happening, why, and how SCP is working to make things better. It is a complex industry and your constituents will have questions and concerns (like was expressed at last night’s meeting). I should have made clear that being an informed, thoughtful and transparent spokesperson for the agency is a responsibility, a privilege, and a requirement of joining SCP.

Please do not hesitate to reach out if any of you have any further questions. I would welcome the opportunity to answer any additional questions you may have.

Have a wonderful weekend!
With appreciation,
Brian Barnacle
Board Chair
Sonoma Clean Power
(707) 373-6414
The SCP Opportunity for Lake County
By Denise Rushing (bio below)
What’s on the Table
On October 21, the Lake County Board of Supervisors will vote on whether to approve the county's involvement in a Joint Powers Agreement (JPA) and authorize the County to join Sonoma Clean Power (SCP)—a public, not-for-profit Community Choice Aggregation (CCA) entity that already provides clean energy to several Northern California counties.

If approved, Lake County residents and businesses could begin receiving electricity generation from SCP in early 2027, with PG&E continuing to maintain the power lines and handle billing and service. Customers would be automatically enrolled but are able to opt out at any time to remain with or return to PG&E generation services.

Lake County is shielded from the costs or financial risks in electricity markets under this agreement.

Lake County would gain two seats on SCP’s 13-member governing board, giving residents a voice in regional energy decisions. The agreement also indicates the County's willingness to explore—but not commit to—a “GeoZone” for local geothermal projects, which could later create jobs and local clean-energy investment opportunities if developed.

Lake County would essentially be committing to two things (1) Participation in the governance of the JPA for a period of 20 years; and (2) A willingness to explore SCP's "GeoZones" concept--a form of generation of vital interest to SCP in the region. 1 While the City of Clearlake declined to join, approval by the County and the City of Lakeport would be sufficient for SCP CCA service to move forward in Lake County.

If Lake County fails to act now, the opportunity to regain local control over energy generation decisions and participate in energy generation benefits may not return for decades, if at all. I would compare this to the decision a BOS made decades ago when forgoing involvement in the Clear Lake dam project and thus losing control and direct benefit from the water in Clear Lake.

The Decision.

Lake County Board of Supervisor's decision can be boiled down to this:
is the BOS willing to enter into a structure that offers their constituents a choice of electricity generation provider?
That decision brings with it essentially one risk: if Lake County residents are dissatisfied with SCP, the county has committed to 20 year involvement in the governance via the JPA. However, in this unlikely event, Lake County constituents are still free to leave SCP and return to PG&E generation service at any time.

This decision does not bind or commit Lake County to geothermal development or any specific geothermal projects. It does ask the board to indicate their willingness to consider such proposals, which may (depending on the individual projects) may have significant benefits or risks to the County. The Board has already indicated an openness to considering such proposals in certain areas.

Given the complexity of the energy markets and the misconceptions and unfounded assertions by a handful of people speaking in opposition to this idea, I've summarized the benefits of the SCP opportunity and done my best to address the concerns raised thus far.
2 Benefits to Lake County Residents and Businesses

1. Fair, Transparent Rates for SCP enrolled participants ● SCP is a public, not-for-profit agency with no shareholders and no profit motive; every dollar goes back into customer programs and rate stability. ● Historically lower than PG&E’s—though not every year—but always fully transparent. 5-7% lower on the TOTAL bill on average. Since generation can be 50% of the PG&E bill, this means SCP lowers the portion it manages by 10-14% on average--sometimes much more.

2. Lake County Leadership
● Lake County has long worked to create a local, circular economy -- keeping dollars in the region. Local Food. Local Energy, Local Money. Energy dollars are a significant economic leak in our region. These dollars leave our region to benefit corporate shareholders based elsewhere. Energy localization is a necessary and natural extension to that localization movement, something we've worked on for decades with modest success. The SCP offer represents one of the best opportunities we have to keep energy dollars in the region. ● Lake County already has a proud history of clean-energy leadership (e.g., major solar installations at county facilities). SCP participation reaffirms that leadership.

3. Clean, Innovative Energy
● SCP’s energy portfolio is cleaner than PG&E’s and its programs consistently among the most innovative in California.
● SCP, along with other CCAs, outperform investor-owned utilities in renewable content and climate innovation.
3 ● SCP prefers local generation and is a proponent of economic localization—investing in Lake County’s projects would keep energy dollars circulating locally.

4. Economic & Community Benefits
● SCP funds cutting-edge programs in energy efficiency, solar, and community energy resilience—among the best in the nation. Our community would directly benefit from these programs.
● Joining SCP could create jobs, attract local investment, and retain economic value within the county instead of exporting it to outside shareholders.

5. Reliability & Choice
● PG&E still owns and maintains the wires, grid, and billing system—service reliability does not change. PG&E is incentivized to maintain its grid ● Customers retain freedom of choice: it’s free to opt out before SCP service begins, and after 60 days, a minimal $5 (residential) or $25 (business) fee apply to opt out.
● SCP will advocate for its constituents in the PG&E rate hearings (for transmission and distribution system rates)--something very difficult (and expensive) for individual counties to do on their own.

6. Local Representation and Control
● For the first time, Lake County will have a real voice in regional energy generation decisions, with two seats on SCP’s 13-member board. ● While two seats doesn't mean local Lake County "control" per se, SCP’s board has a strong record of collegiality and trustworthiness—it 4 respects local priorities. SCP has never imposed unwanted projects on its member communities. We would be one of their member communities with a seat at the table.
● The alternative? No voice at all in which SCP projects get proposed and where they are developed. Projects developed here (SCP or corporate) would have much less benefit to our County and there would be little incentive for the developer to do so.

Key Myths & Misunderstandings (to Address Directly)
In hearings thus far, members of the general public have brought forward questions and made assertions. Their tone tends to be emotional and distrustful, and these concerns are understandable--given decades of outside interests exploiting the natural assets of this county. Most of these concerns are based on misunderstandings that can be directly addressed.

1. “Isn't this just a backdoor for geothermal expansion?” Fear that the “GeoZone” concept binds the County to unwanted geothermal projects that we would not otherwise see.

2. “Won't the County be financially liable if something goes wrong?” Misunderstanding of how a Joint Powers Agreement (JPA) actually isolates risk.

3. “PG&E has said their rates will go down. Isn't there a risk that SCP might not be lower?”
Skepticism about long-term savings or comparisons with PG&E.

4. “Aren't we giving up local control?”
Concern that decisions will be made outside of Lake County and not to the 5 county's benefit.

5. “PG&E will retaliate or shut us out.”
Concern that PG&E could punish Lake County or degrade service quality.

6. “It’s too complicated—let’s just wait.”
Fear of change or belief that delay carries no cost.

7. “The board should get a better deal from SCP.”
Misunderstanding and assumptions that there’s a separate negotiation and better deal to be had.

8. "Why can't Lake County develop clean energy and geothermal on its own?" Belief that the county has the knowledge, resources, energy demand, and public support to develop its own energy projects.

9. “We should go slow. Why the hurry?”
Belief that postponing the decision avoids risk when, in reality, it forfeits a rare opportunity.

Let's go through these one at a time.

Fact: The GeoZone is not a project—it’s a conversation starter.

Sonoma Clean Power wants Lake County at the table as it studies where geothermal development might make sense regionally. The GeoZone is an exploratory concept, not a commitment to specific projects in this agreement.

If any project were proposed, it would require permits and review—meaning Lake County keeps any authority it already has over such projects. Note: Lake's authority changes if developers choose to apply to the state for permits rather than the 6 county, but accepting this SCP proposal does not lessen Lake County's power, it strengthens it. Once in partnership, Lake County can request that (a) local projects go through the county processes and (b) SCP help in amending State clean energy permitting legislation to comply with local Geothermal setbacks. Regardless of whether or not Lake County joins SCP, the county must and should separately clarify and update its own geothermal setbacks--and make known to the state and any developer where such development is deemed acceptable and unacceptable in our county, amending state legislation if need be. It's important to note that every project large and small, particularly complicated ones like those SCP might propose, have risks associated with them.

By participating now, we keep the county's authority and we put ourselves in the best position to ensure that, if SCP geothermal projects do happen, they are done on Lake County’s terms, creating local jobs and local revenue—not simply handed off to big outside organizations and corporations like Chevron or Shell, which could move forward regardless--taking their requests to the state if they so choose.

In short: joining SCP gives us a voice, not an obligation.

Fact: Lake County takes on zero financial risk in the energy markets.

The Joint Powers Agreement (JPA) ensures that Sonoma Clean Power—not Lake County—signs all contracts and carries any project-related financial obligations. The County does not invest, guarantee, or borrow money for SCP operations.

If SCP ever faced financial trouble (a highly unlikely scenario given its excellent track record and strong reserves), the worst case is that the agency could dissolve and customers would simply return to PG&E as before—no bills, no liabilities, no taxpayer exposure.
7 If SCPs customers (including the County facilities) do not like the arrangement, they are free to return to PGE's portfolio for a nominal fee. It should be noted that SCP has a high customer satisfaction rate and retains 87% of eligible area participants, so a scenario where customers demand Lake County exit the JPA before the end of its term is highly unlikely. The only financial obligation the county could face is under this unlikely scenario because SCP would have made long term investments to serve its Lake County customers.

In other words, joining SCP allows Lake County to share in the benefits of a public power agency with little or no financial risk to the County or its residents.

Fact: SCP’s rates have been consistently competitive—and always transparent.

For most of the past decade, Sonoma Clean Power customers have paid 5–7% less in their TOTAL bill than PG&E customers on average. Rates fluctuate with market conditions for both agencies, but SCP has a strong Rate Stabilization Fund that helps buffer sudden cost spikes.

When PG&E lowered its rates in early 2024, SCP immediately followed suit, maintaining roughly a 3% overall savings for its customers.

Unlike PG&E, SCP is not profit-driven—it has no shareholders to pay, and rate decisions are made locally, in public meetings. SCP’s pricing is about fairness and accountability, not corporate profit. Their motive is customer satisfaction and Community Choice--with priorities of economic localization and a clean energy future.

Even when prices are close, SCP delivers more value: cleaner energy, better customer-facing programs, and renewable energy projects that reinvest in local jobs right here in our region.
8 For some customers, this is the only viable way they can "go solar." For those who can, or already have gone solar--their arrangements are preserved and in the future may be more advantageous.

Fact: Joining SCP gives Lake County a voice we’ve never had before.

Right now, PG&E (as the generation supplier of last resort) and other large generation companies make all major energy decisions in their various corporate headquarters, with zero representation from Lake County and no way for our residents to influence rates, programs, or investments short of becoming an intervenor at the CPUC in PG&E's case.

By joining Sonoma Clean Power, Lake County gains two seats on SCP’s board—a transparent, collaborative body made up of elected officials from member counties and cities. The board’s track record shows respect for local priorities and (again) no history of imposing unwanted projects.

Through SCP, Lake County can help shape regional energy decisions that affect our homes, our economy, and our environment—something we’ve never had under PG&E’s monopoly.

Far from losing control, this move means taking back control—from a corporation to the regional community.

Fact: PG&E has no reason—and no incentive—to retaliate.

PG&E does not make its profits from generating electricity—the part that Sonoma Clean Power would handle. PG&E earns money by maintaining infrastructure (the 9 poles and wires) and through rates approved by the California Public Utilities Commission (CPUC) based on its performance.

That means PG&E continues to make money serving SCP customers, because it still delivers the electricity, maintains the grid, and handles billing—just as before.

Since Community Choice programs began in California, dozens of cities and counties have joined, and PG&E has never retaliated. It’s not only illegal under state law, it’s also not in their financial interest. In short: PG&E doesn’t lose when Lake County joins SCP—we just gain a choice and a stronger local voice over where our energy comes from.

Fact: SCP's Offer is unlikely to improve.

It is clear that the BOS does not have significant leverage to gain many, if any concessions from SCP on this offer, especially given actions at the state that could enable any energy developer to bypass the county permitting process. Still, the Board of Supervisors can and should ask for important clarifications and highlight items of importance to Lake County, especially working with the County on areas suitable for Geothermal projects.

SCP, in its offer, is extending the intention of partnership (as it has with all of its member communities). Given the relatively difficulty of serving Lake County customers for the load we bring to SCP, this offer of partnership is a strong one.

It offers us benefits for our population, real influence and a seat at the table.

Once in the door, Lake County could advocate for increased voting shares based on power production as well as consumption, giving SCP incentive and Lake more leverage as these projects are proposed.
10 Fact: Developing large local energy projects ourselves to serve our community is costly, complex, and risky. These projects would still require interconnection with PG&E, a multi-year process.

Constituents have asked: "Why can't Lake County develop clean energy and geothermal on its own?" They have asserted that if we decide to do this it would be in the best interests of the county. As the county is already a leader in solar energy installations on it's own facilities and with its own water and sewer districts, this is a reasonable question.

While the county can and should continue to develop renewable energy projects for its own facilities, the county is not in a financial position to develop its own geothermal wells or other major projects requiring PG&E interconnection without expensive outside expertise and massive risk to the county's own financial well-being. These are risks most citizens would find unacceptable.

Fact: Waiting is the real risk —this opportunity may not come again.

Lake County has explored local energy options for over 20 years, but until now, the timing was never right. When we first looked at Community Choice Aggregation (CCA) in 2015, the financial risk for that proposal fell on the County. In subsequent years , PG&E’s exit fees made participation in a CCA like SCP uneconomical. Back then, even SCP wasn’t ready—they were new and cautious, building their own expertise in volatile energy markets.

Today, that’s changed. SCP now has a proven, decade-long track record of success, a strong financial foundation, and PG&E exit fees are no longer a significant financial barrier, though that could change in the future. For the first time, the economics and structure align to make this work for both Lake County and SCP. 11 If we delay, we risk losing a rare, favorable moment—just as we once lost control of our own lake’s water by waiting too long to act.

And the “complexity” isn’t on residents’ shoulders. SCP manages implementation professionally—they’ve done this many times before and have award-winning community programs. All residents will need to do is choose whether to stay in or opt out.
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The bottom line: the SCP option is not a burden to take on—it’s a door we simply need to walk through, before it closes.
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About Denise Rushing
Denise Rushing is a former Lake County District 3 Supervisor and a recognized leader in renewable energy and energy efficiency. She earned a degree in environmental engineering from Stanford University and devoted her thirty-five plus year career in the energy industry to clean technology. Her pioneering work included the launch of award winning energy efficiency and clean technology initiatives adopted by utilities around the world. She has led and advised disruptive energy technology start-ups and worked with energy industry innovators. Key roles included Vice President of Marketing and Sales for eMeter, CellNet Data Systems, and Sage Systems, General Manager for Invensys Goodwatts home energy control division, and Manager of the California Clean Energy fund.

From 2007-2015, she served two terms on the Lake County Board of Supervisors where she led the county to two state-wide Green California Leadership awards and championed two of the largest public solar energy installations in the Western United States. 12 Meeting Date: 10/21/2025 Page 1 Agenda Item #VII.A.1. 418793.1

CITY OF LAKEPORT
City Council ☒
City of Lakeport Municipal Sewer District ☐
Lakeport Industrial Development Authority ☐
Municipal Financing Agency of Lakeport ☐

STAFF REPORT
RE: Consideration and Approval of Term Extensions for On-Call Consultant Contracts
MEETING DATE: 10/21/2025
SUBMITTED BY: Ron Ladd, Public Works Director
PURPOSE OF REPORT: ☐Information only ☐ Discussion ☒Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

The City Council is being asked to authorize the City Manager to execute amendments extending the terms of twelve (12) on-call contracts for design professional and consultant services.

BACKGROUND/DISCUSSION:

The development of on-call contracts for design professionals and consultants is becoming a best practice for small rural cities that do not have ready access to specialized consultant services. The establishment of a vetted and pre-qualified list of professionals is an effective tool for City staff to streamline the design and engineering processes for the City’s numerous capital improvement projects. Additionally, these on-call design professionals and consultants are assistive in the City’s pursuit of various grant opportunities that often require technical expertise from a specialist on a tight deadline.

The City solicited for On-Call Consulting contracts to provide engineering, survey, right-of-way, environmental studies and a variety of other services in 2022. The City Council authorized execution of Professional Service Agreements with 15 firms that were determined to be qualified under the guidelines of the Request for Qualifications (RFQ).

Over the last 3 years, the firms on the on-call roster have assisted with the 2024 Water & Sewer Main Replacement design, environmental studies related to the Natural High Demolition, design of the Martin & Lakeshore Repaving Project, the Navigation Center Feasibility Study, design of a new sodium hypochlorite treatment system at the wastewater treatment plant, geotechnical investigation and design of a new production well, updating the water and sewer master plans, design of parking lot improvements at the Lakeport Fire District Station 50, and various other public works, utility and Community Development needs.

All agreements had a term of 3 years with the ability to extend in one-year increments for a total of 5 years as outlined in the original RFQ. This request is to authorize the City Manager to execute amendments with 12 firms to extend the term of their Professional Services Agreement by one year. The not-to-exceed value of each agreement remains the same and there is no change to the scope of services. The contracts will continue to be paid for on a project basis and will mostly be paid out of specific project accounts. There is no obligation for the City to spend any or all of this money and will only pay for work performed.

Meeting Date: 10/21/2025 Page 2 Agenda Item #VII.A.1.
418793.1
Staff recommends extending the agreement term by one year for the following firms:

1. Borrelli & Associates

2. Crawford & Bowen Planning, Inc.

3. Dokken Engineering

4. Dudek

5. EBA Engineering

6. Endemic Environmental

7. MC Engineering

8. PACE Engineering

9. R.E.Y. Engineers, Inc.

10. RSA+

11. Vanir

12. Wood Rodgers
OPTIONS:

1. Move to authorize City Manager to execute amendments to extend the terms of twelve on-call agreements by one year.

2. Provide other direction.

FISCAL IMPACT:
☒ None ☐ $ Budgeted Item? ☒Yes ☐ No
Budget Adjustment Needed? ☐Yes ☒ No If yes, amount of appropriation increase: $ Affected fund(s): ☒ General Fund ☒ Water OM Fund ☒ Sewer OM Fund ☐ Other:

Comments: Consultant work product will be paid through budgeted funds for individual capital improvement projects. If additional funds are needed, staff will present desired amendments to Council for appropriation at that time.

COUNCIL PRIORITIES:
☐ Priority #1: Public Safety & Crisis Response
☐ Priority #2: Disaster Resiliency
☒ Priority #3: Good Governance & Fiscal Stability
☒ Priority #4: Capital Infrastructure Improvement
☐ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Move to authorize City Manager to execute amendments to extend the terms of twelve on-call agreements by one year.
☒ Attachments: 1. Original RFQ Solicitation

2. Sample Amendment

CITY OF LAKEPORT

REQUEST FOR QUALIFICATIONS
for
On-Call Engineering and Consulting Services
for the City of Lakeport
225 Park Street
Lakeport, CA 95453
August 15, 2022
Qualifications must be received no later than
5:00 PM, September 16, 2022

A. Introduction
The City of Lakeport is seeking qualified firms or individuals to provide a variety of professional engineering services under the direction of the Public Works & Engineering Department on an on-call basis. Services include, but are not limited to, civil engineering, water and wastewater engineering, land surveying, environmental compliance and permitting, right-of-way services, project management, construction inspection, and materials testing. Interested firms, teams or individuals are invited to submit a response in the form of a Statement of Qualifications (SOQ). Respondents are not expected to provide all services and single discipline SOQs will be accepted.

Each of the qualified consultants will then be eligible to perform work for the City, as needed, for specific projects or tasks. The City anticipates the total cumulative on-call contracts awarded through this RFQ to total $900,000 for the next three fiscal years. This RFQ and any subsequent professional services agreement do not guarantee work under the agreement, it simply qualifies those on the list to be called upon during the term of their agreement.

When a specific project comes up, the City will contact one or more of the qualified firms offering the services requested for the project. Notifications will include a description of work to be performed, expected duration of work or deadlines, expected deliverables, and requirements and due date of response to notification. If there are multiple firms offering the services requested, a competitive task order procedure will be followed. Interested consultants shall submit a brief proposal with the project specific deadline along with expected fees. Proposals will be ranked based on project understanding, previous experience of assigned staff, ability to meet the timeline and cost effectiveness. Once selected, the chosen firm will be issued a Task Order that includes the scope of work, schedule and negotiated “Not to Exceed” payment amount.

The City, at its sole discretion, has the right to negotiate and issue Task Orders directly if it is determined appropriate by the Public Works Director or City Manager.

B. Potential Scope of Services
The City of Lakeport anticipates the need for a wide range of engineering and consulting services to support the growth of the community. Projects could include, but are not limited to, roadway reconstruction, pedestrian improvement projects, water line replacement, sewer line replacement, storm drain system development, emergency repairs, development of funding/grant applications, environmental studies, and surveying. The specific scope of services anticipated are outline below.  City Engineer Services- Acting as the City’s Engineer. General consulting related to water, wastewater, storm drain, street projects, planning and other projects for the City. Technical evaluation of projects and plan reviews. Assist with project planning, estimating, scheduling, budgeting, preparing bid documents, bidding, and construction management. Provide engineering review of encroachment permit applications and execution. Provide engineering review of development permits involving construction of street improvements including curb, gutter and sidewalk. Represent the City within the community and with outside agencies. Attend meetings as requested by the City such as City Council meetings, Technical Advisory Committee, Ad Hoc Committee meeting, other City organized meetings, as well as meetings with outside agencies and community groups as needed. Prepare, review, and present staff reports and City engineering documents and reports on various projects and programs. Provide technical support, review, and sign technical reports prepared by City staff for compliance with regulatory agencies.

Participate in the preparation of the annual fiscal year budget; provide oversight of requests for 2 | P a g e
proposals and/or construction services including advertising and bid management for projects; evaluation of proposals and recommendation for project award; and negotiation and project management assistance for capital improvement projects.

Participate in the review of planning applications in relation to the City’s General Plan, infrastructure master plans, and overall capital needs of the City; assist with the City’s compliance with all Federal, State, County, and local laws and regulations; and assist in managing projects that are Federally, State, or County funded following required policies including Caltrans Local Assistance Procedures Manual. Monitor and make recommendations in relation to changes in laws, regulations and technology that may affect City operations and implement policy and procedural changes as required. Review and comment on planning programs and land development controls.

Review and update City Improvement Standard Plans and Specifications as needed.  Preliminary Engineering Studies-Develop general project locations and design concepts and related activities needed to establish the parameters for final design such as geometrics, hydraulics, geotechnical, alignments, typical sections, landscape architecture, traffic operations, electrical, ITS elements, etc. Complete project specific studies for funding agencies such as the California Transportation Commission, Caltrans and others. Studies could include geotechnical investigations, hydrologic and hydraulic studies, topographic surveys and right-of-way surveys.

Develop Project Study Report and Project Study Report-Equivalent documents.  Surveys and Mapping – Data collection, mapping and surveying necessary for preliminary engineering, design, cost estimates, right-of-way impacts, and environmental clearance. The scope of comprehensive base mapping and surveying includes but is not limited to Control Surveys, Aerial Photogrammetry, LiDAR, Limited Design Level Topographic Surveys, Right-of-Way Retracement, Lot Line Adjustments, and Records of Survey.  Environmental Studies and Documentation – Complete environmental reviews; including submitting the Caltrans Preliminary Environmental Study and preparing any required technical studies to complete the NEPA document, including but not limited to, project description narratives, APE maps, cultural resource studies, historic property survey reports, archaeological survey reports, special status plant and animal survey reports, wetland delineation reports, natural environment study, location hydraulic study, initial site assessments, visual impact assessment memos, visual resources technical memos. Preparation and/or assistance to City staff to prepare CEQA documents. Observation, surveys and reporting required as a result of environmental document mitigation measures. Prepare and submit environmental permit applications to various agencies, including but not limited to, the Army Corp of Engineers, Regional Water Quality Control Board, and California Department of Fish & Wildlife. Prepare Storm Water Pollution Prevention Plans as required.
 Utility Coordination – Submit improvement plans to utility companies in accordance with their requirements to receive review and comment. Coordinate utility relocations, including relocation of the utility poles, as needed.
 Right of Way Services – Prepare legal descriptions for permanent right of way acquisitions and temporary construction easements, acquire all necessary title reports, prepare right of way plats, prepare right of way certifications for state and federally funded projects, stake right of way limits, complete Record of Survey. Real property appraisals, appraisal review, acquisitions could be 3 | P a g e
necessary. Consultants acquiring right of way for the City will be expected to fully comply with all federal and state laws as required by the project specific funding.  Design & Drafting –Prepare plans, technical specifications, and estimates in accordance with City and Caltrans Standards to achieve project objectives. Consultant shall examine and present project alternatives, as necessary, which complete project goals within construction budget. Projects could include transportation improvements, pedestrian improvements, water treatment, storage and distribution, wastewater collection and treatment, stormwater management, conveyance and treatment, building upgrades, structural remodels for ADA compliance, generated power integration, and other capital improvement projects. Services from architects, civil, mechanical, electrical, structural, and geotechnical engineers are expected.  Bid Support Services – Oversee the bidding process and distribute the project documents to plan rooms and contractors. Consultant shall respond to questions that arise during the bid phase, prepare addendums, maintain a bidder’s list, and attend pre-bid meetings as necessary. Assist with project planning, scheduling, budgeting, and construction management.  Project Management/Construction Engineering –Project management includes but is not limited to, coordinating and being responsible for scheduling meetings, managing the project schedule, preparing and distributing minutes, field reviews, tracking action items for the City of Lakeport and consultant sub-contractors, review submittals, labor compliance reviews, provide updates on project status, review project designs and resolve issues, develop change orders and respond to RFI’s, provide construction inspection and observation including reports and photographs, provide materials testing services, track quantities and review progress payments, perform onsite labor compliance interviews, complete and/or review as-built drawings and prepare documentation for funding compliance and project close out reporting.  Stormwater Management Services-Provide services related to management of the City’s storm water program as required by the State issued Phase II Municipal Separate Storm Sewer System (MS4) General Permit and other regulatory mandates. Services could include preparing reports, plans, procedures, assessments, surveys related to the MS4 General Permit. Conduct water sampling, testing and monitoring of stormwater and prepare Preparation of a Storm Water Pollution Prevention Plans (SWPPP) as required. Provide technical assistance and recommendation for Best Management Practices (BMPs) for treating storm water run-off. Monitor construction sites for compliance with the site SWPPP.
 Computer Software/Technical- GIS implementation and management. SCADA Integration support: troubleshoots, analyzes, repairs, reports on, and recommends/performs service of SCADA, PLC, instrumentation, motor controls and process analyzers. Programming/upgrading existing logic to modify operations as needed for operations.  Grant Support-Research the availability of federal, state and private grant/funding programs to identify potential funding sources that may be appropriate for the betterment of the City. This could include, but not limited to, housing; infrastructure; parks and recreational facilities and disaster related needs such as prevention, recovery, resiliency and mitigation. Prepare and submit grant applications. Complete requests for information, supplemental grant documents, track status of award and assist with grant requirements post-award. The consultant would be expected to assist with grants from, at minimum, the following agencies and programs: FEMA, FHWA, CDBG, USDA, ATP, HSIP, ER, Department of Boating and Waterways, Department of Parks and Recreation.
4 | P a g e
 Miscellaneous- Develop Requests for Proposals, Qualifications, Bids or provide technical information to procure other services or products.

C. PROPOSAL REQUIREMENTS
Each technical proposal shall contain as a minimum, the following elements:

1. Introductory Letter
The introductory letter shall be addressed to:

City of Lakeport
Attn: Olivia Grupp, Project Manager
225 Park Street
Lakeport, CA 95453
The letter shall be on consultant’s letterhead and include the consultant’s contact name, mailing address, telephone number, and email address. The letter will clearly state the scope of services the consultant provides, understanding of the City’s needs, and any other pertinent information the consultant believes should be included. All addendums issued must be acknowledged in the introductory letter. Indicate if any changes are requested to the proposed professional services agreement, otherwise indicate it will be signed without modifications. Indicate the consultant is able to commence work immediately following execution of an agreement, and that the City’s insurance requirements can be met.

The letter shall be signed in blue ink by the individual authorized to bind the consultant to the proposal.

2. Scope of Services Provided
Consultant’s SOQ must clearly identify the proposed discipline(s) and/or general service area(s) of interest listed in the “Scope of Services” section. Include a detailed Scope of Work Statement describing all services to be provided. Describe project deliverables for each phase of your work. Describe your project tracking and reporting methods to ensure tasks are delivered on-schedule and within budget.

3. Personnel
The SOQ must include an organizational chart illustrating key staff and their positions. The prospective consultant shall describe the qualifications of all professional personnel to be employed, including a summary of similar work or studies performed, a resumé for each professional, a statement indicating what services/tasks each professional will provide/perform. The consultant shall not cause members of the project team to be substituted without prior written approval of the City of Lakeport. The prospective consultant shall designate by name the project manager to be assigned to this contract. The selected consultant shall not cause the substitution of the project manager without prior written approval of the City of Lakeport.

4. Sub‐consultants
If sub-consultants are to be used, the prospective consultant must submit a description of each person or firm and the work to be done by each sub-consultant. All sub-consultants that potentially will be utilized throughout the contract period by the consultant must be listed in the proposal. 5 | P a g e

5. References
The prospective consultant shall provide names, addresses and telephone numbers for at least three clients for whom the prospective consultant has performed work similar to that proposed in this request. A summary statement for each assignment shall be provided.

6. Conflict of Interest Statement
Throughout the term of the awarded contract, any person, firm or subsidiary thereof who may provide, has provided or is currently providing design engineering services and/or construction engineering services under a contractual relationship with a construction contractor(s) on any City of Lakeport project listed in this Scope of Work must disclose the contractual relationship, the dates and the nature of the services. The prime consultant and its sub-consultants shall also disclose any financial or business relationship with the construction contractor(s) who are working on the projects that are assigned for services through task orders on the contract.

Similar to the disclosures regarding contractors, all firms are also required to disclose throughout the term of the awarded contract, any design engineering services including claim services, lead project management services and construction engineering services provided to all other clients on any City of Lakeport project listed in this Scope of Work.

In addition to the disclosures, the consultant shall also provide possible mitigation efforts, if any, to eliminate or avoid any actual or perceived conflicts of interest.

The consultant shall ensure that there is no conflict before providing services to any construction contractor on any of the City’s projects’ listed in this Scope of Work. The submitted documentation will be used for determining potential conflicts of interest. The City will use this documentation to determine whether the firm may work on specific projects.

If a consultant discovers a conflict during the execution of an assigned task order, the consultant must immediately notify the City of Lakeport Contract Manager regarding the conflicts of interest. The City’s Contract Manager may terminate the Task Order involving the conflict of interest and the City may obtain the conflicted services in any way allowed by law. Failure by the consultant to notify the Contract Manager may be grounds for termination of the entire contract.

7. Fee Schedule
Submit a fee schedule either in a sealed envelope via mail OR in a password protected .pdf file via email.

See the proposal submittal information below for address and email.

The proposed fee schedule shall include proposed hourly rates for calendar years 2022-2025 for all primary staff, including all subconsultants. List all other reimbursable fees and expenses anticipated based on the services provided.

Certified payroll is required when applicable. Consultants will be required to submit payrolls to the Department Industrial Relations and the City per all applicable labor compliance codes.

The fee schedule will not be used during the consultant evaluation process but may be used by the City of Lakeport during the negotiation process. The City will request the password to electronically submitted fee schedules after the proposals have been evaluated and scored. 6 | P a g e
When invoicing, receipts are required to be submitted for all direct costs, other than fully-weighted personnel costs. If sub-consultants are to be used, the breakdown of subcontract costs shall follow the same format as that for the prime consultant.

D. CONSULTANT AWARD

1. Statement of Qualifications Review
Each SOQ will be reviewed to determine of it meets the requirements. Failure to meet the requirements for the Request for Qualifications will be cause for rejection.

The City of Lakeport may reject any SOQ if it is conditional, incomplete, or contains irregularities. The City of Lakeport may waive an immaterial deviation in a SOQ. Waiver of an immaterial deviation shall in no way modify the Request for Qualifications document or excuse the proposer from full compliance with the contract requirements if the proposer is awarded a contract. The City of Lakeport may also reject all submittals.

2. Selection Criteria
An evaluation committee will evaluate those SOQs that meet the requirements and will determine whether interviews will be needed. The City of Lakeport reserves the right to select a consultant based solely on written statements. SOQs will be evaluated based on the following criteria:

Scoring will be as follows:
o Experience & technical competence of the firm as it relates to the services provided (20 points)
o Understanding of the work to be performed (20 points) o Familiarity with City, State and Federal procedures (20 points) o Team organization and key personnel experience (20 points) o Methods and capability to accomplish work on schedule (20 points) Total Points Possible (100 points)

3. Contract Award
Qualified consultants must be prepared to enter into the City’s standard agreement, a sample of which is included as Attachment A of this RFQ. Please review the details of Attachment A. By reference, the agreement incorporates many standards, terms and conditions required as part of this RFQ. The City intends to award contracts substantially in the form of the sample agreement to the selected consultant(s).

This RFQ and the consultant’s SOQ may be made part of any resultant contract. Any exceptions taken to the form of the sample agreement presented in Attachment A must be disclosed in the Introductory Letter.

Consultants that take exception to the City’s standard terms and conditions do so at the risk that the consultant’s SOQ may be declared to be nonresponsive and not considered for contract award. 7 | P a g e
E. GENERAL INFORMATION

1. Proposal Submittal
The SOQ shall be submitted electronically via email or on a USB flash drive via mail to:

City of Lakeport-Public Works
Attn: Olivia Grupp
225 Park Street
Lakeport, CA 95453
[email protected]
Fee schedules are only to be submitted in a separate sealed envelope OR via email as a password protected file.

2. Submittal Deadline
Submittals are due no later than 5:00 PM on Friday, September 16, 2022. Postmarks will not suffice.

Submittals received after the specified time will not be considered and will be returned to the offeror. Fee schedules sent separately are considered part of the entire SOQ, therefore must be submitted by the same deadline. Submission of a proposal will signify the consultant’s agreement that his/her proposal is valid for at least ninety (90) days from the date of opening.

3. Modification or Withdrawal of Submittal
Any SOQ received prior to the date and time specified above for receipt of SOQ may be withdrawn or modified by written request of the consultant. To be considered, however, any modified SOQ must be received by the date and time specified above.

4. Consultant Selection Schedule
The tentative schedule of activities related to the Request for Qualifications is as follows:

Activity Date
Request for Qualifications issued August 15, 2022
Written Question Submittal Deadline September 5, 2022 at 5:00 PM SOQ Submittal Deadline September 16, 2022 at 5:00 PM
Agency review completed by September 23, 2022
Interviews and Negotiations completed by September 23, 2022 Council Award October 4, 2022

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5. Property Rights
Submittals received within the prescribed deadline become the property of the City of Lakeport and all rights to the contents therein become those of the City. After the date specified for the opening of the RFQ, all materials received relative to this solicitation will become public information and be available for inspection. The City reserves the right to retain all submittals, whether or not the respondent is selected or judged to be responsive.

6. Amendments to Request for Qualifications
The City of Lakeport reserves the right to amend the Request for Qualifications by addendum prior to the final date of SOQ submission. All addenda will be posted on the City of Lakeport’s website at:
https://www.cityoflakeport.com/bid_opportunities.php
.

7. Non-commitment of the City of Lakeport
Upon receipt, each SOQ becomes the sole property of the City and will not be returned to the Respondent.

Each Respondent is solely responsible for the costs it incurs to prepare and submit its SOQ. The City reserves, in its sole discretion, the right to reject any and all SOQs, including the right to cancel or postpone the RFQ or the Project at any time, or to decline to award the Agreement to any of the Respondents. The City reserves the right to waive any immaterial irregularities in a SOQ or submission of a SOQ. The City reserves the right to select a consultant based solely on written proposals. The City reserves the right to reject any SOQ that is determined to contain false, misleading, or materially incomplete information.

8. Payment & Performance Period
The City will execute a Professional Services Agreement (Agreement) that will include a scope of services and associated “Not to Exceed” payment amount. The City has the discretion to determine the “Not to Exceed” amount based on their anticipated needs. Agreements will have a performance period of 3 years with an option to extend 2 years (1-year extensions, no more than twice and not to exceed 5 years total). Payment terms will be project specific.

The City will assign service requests (Task Orders) as determined appropriate by the Director of Public Works or City Manager. The selected consultant(s) will be responsible for completing tasks and milestones according to a negotiated timeline. Tasks may be added and/or redefined based on subsequent negotiations. Upon execution of an Agreement with the City, consultant(s) will meet with staff to discuss/clarify the desired goals and outcomes of the Agreement.

9. Questions
Questions regarding this Request for Qualifications will only be accepted in writing via email. All questions should include the individual's name, the name of the firm, address, telephone number, and e-mail address.

Questions must be submitted no later than 5:00 pm on September 5, 2022, to:

Olivia Grupp-Project Manager
City of Lakeport
[email protected]
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Questions and answers will be provided in the form of an addendum to this RFQ, and will be posted on City of Lakeport’s website as noted in Section E-6 above.

10. Affirmative Action
Prospective consultants should be aware that the Equal Employment Opportunity Requirement of Executive Order 11246, as amended by Executive Order 11275, Title VII of the Civil Rights Act of 1964, the California Fair Employment Practices Act and other federal and state laws pertaining to equal employment opportunity are applicable to any contract awarded by the City of Lakeport.

11. Disputes Relating to Proposal Process
In the event a dispute arises concerning the selection process prior to the award of the contract, the party wishing resolution of the dispute shall submit a request in writing to the City Manager within five calendar days of the date of the recommendation award or denial letter.

City of Lakeport
Attn: Kevin Ingram, City Manager
225 Park St.

Lakeport, CA 95453
[email protected]
Grounds for an appeal is that the City failed to follow the selection procedures and adhere to requirements specified in this RFQ or an addenda or amendments thereto; there has been a violation of conflict of interest as provided by California Government Code section 87100 et seq; or violation of Federal or State law. The City will consider only those specific issues addressed in the written appeal. The protest will be reviewed by the City Manager in consultation with the City Attorney, and their determination on the protest is final. No public hearing will be held on the protest. Time being of the essence, the City reserves the right to proceed with award of the agreement and commencement of the services notwithstanding any pending protest or legal challenge.

12. Conflict of Interest
City of Lakeport employees are prohibited from participating in the selection process for this RFQ if they have any financial or business relationship with any respondent. This RFQ process will be conducted in compliance with all laws regarding political contributions, conflicts of interest, or unlawful activities, including, but not limited to, the City’s Conflict of Interest Policy.

Attachment A Sample Professional Services Agreement–City of Lakeport

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ATTACHMENT A
Sample Professional Services Agreement–City of Lakeport

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PROFESSIONAL SERVICES AGREEMENT

FOR ON-CALL DESIGN PROFESSIONAL SERVICES
(City of Lakeport / [Company or Individual])

1. IDENTIFICATION
This ON-CALL PROFESSIONAL SERVICES AGREEMENT (“Agreement”) is entered into by and between the City of Lakeport, a California municipal corporation (“City”), and ______________________, a ____________________________ (“Consultant”).

2. RECITALS

2.1. City has determined that it requires the following professional services from a consultant: [enter description of consultant’s services]

2.2. Consultant represents that it is fully qualified to perform such professional services by virtue of its experience and the training, education and expertise of its principals and employees. Consultant further represents that it is willing to accept responsibility for performing such services in accordance with the terms and conditions set forth in this Agreement.

2.3. Consultant represents that it has no known relationships with third parties, City Council members, or employees of City which would (1) present a conflict of interest with the rendering of services under this Agreement under Government Code Section 1090, the Political Reform Act (Government Code Section 81000 et seq.), or other applicable law, (2) prevent Consultant from performing the terms of this Agreement, or (3) present a significant opportunity for the disclosure of confidential information.

NOW, THEREFORE, for and in consideration of the mutual covenants and conditions herein contained, City and Consultant agree as follows:

3. DEFINITIONS

3.1. “Design Professional”: A Design Professional is any individual satisfying one or more of the following: (1) licensed as an architect pursuant to Business and Professions Code 5500 et seq., (2) licensed as a landscape architect pursuant to Business and Professions Code 5615 et seq., (3) licensed as a professional land surveyor pursuant to Business and Professions Code 8700 et seq., or (4) registered as a professional engineer pursuant to Business and Professions Code 6700 et seq.

3.2. “Scope of Services”: Such professional services as are set forth in Consultant’s [enter consultant’s proposal date] proposal to City attached hereto as Exhibit A, as well as 12 | P a g e
any executed Task Orders attached as Exhibits which shall be incorporated herein by this reference.

3.3. “Agreement Administrator”: The Agreement Administrator for this project is [Name and title]. The Agreement Administrator shall be the principal point of contact at the City for this project. All services under this Agreement shall be performed at the request of the Agreement Administrator. The Agreement Administrator will establish the timetable for completion of services and any interim milestones. City reserves the right to change this designation upon written notice to Consultant

3.4. “Approved Fee Schedule”: Consultant’s compensation rates are set forth in the fee schedule attached hereto as Exhibit B and incorporated herein by this reference. This fee schedule shall remain in effect for the duration of this Agreement unless modified in writing by mutual agreement of the parties.

3.5. “Maximum Amount”: The highest total compensation and costs payable to Consultant by City under this Agreement. The Maximum Amount under this Agreement is ____________________ Dollars ($_______________).

3.6. “Commencement Date”: [date].

3.7. “Termination Date”: [date].

4. TERM
The term of this Agreement shall commence at 12:00 a.m. on the Commencement Date and shall expire at 11:59 p.m. on the Termination Date unless extended by written agreement of the parties or terminated earlier under Section 18 (“Termination”) below. Consultant may request extensions of time to perform the services required hereunder. Such extensions shall be effective if authorized in advance by City in writing and incorporated in written amendments to this Agreement.

5. CONSULTANT’S DUTIES

5.1. Services. Consultant shall perform the services identified in the Scope of Services. City shall have the right to request, in writing, changes in the Scope of Services. Any such changes mutually agreed upon by the parties, and any corresponding increase or decrease in compensation, shall be incorporated by written amendment to this Agreement via Task Order or other written instrument.
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5.2. Coordination with City. In performing services under this Agreement, Consultant shall coordinate all contact with City through its Agreement Administrator.

5.3. Budgetary Notification. Consultant shall notify the Agreement Administrator, in writing, when fees and expenses incurred under this Agreement have reached eighty percent (80%) of the Maximum Amount. Consultant shall concurrently inform the Agreement Administrator, in writing, of Consultant’s estimate of total expenditures required to complete its current assignments before proceeding, when the remaining work on such assignments would exceed the Maximum Amount.

5.4. Business License. Consultant shall obtain and maintain in force a City business license for the duration of this Agreement.

5.5. Professional Standards. Consultant shall perform all work to the standards of Consultant’s profession and in a manner reasonably satisfactory to City. Consultant shall keep itself fully informed of and in compliance with all local, state, and federal laws, rules, and regulations in any manner affecting the performance of this Agreement, including all Cal/OSHA requirements, the conflict of interest provisions of Government Code § 1090 and the Political Reform Act (Government Code § 81000 et seq.).

5.6. Avoid Conflicts. During the term of this Agreement, Consultant shall not perform any work for another person or entity for whom Consultant was not working at the Commencement Date if such work would present a conflict interfering with performance under this Agreement. However, City may consent in writing to Consultant’s performance of such work.

5.7. Appropriate Personnel. Consultant has, or will secure at its own expense, all personnel required to perform the services identified in the Scope of Services. All such services shall be performed by Consultant or under its supervision, and all personnel engaged in the work shall be qualified to perform such services. [Name of Project Manager] shall be Consultant’s project administrator and shall have direct responsibility for management of Consultant’s performance under this Agreement. No change shall be made in Consultant’s project administrator without City’s prior written consent.

5.8. Substitution of Personnel. Any persons named in the proposal or Scope of Services constitutes a promise to the City that those persons will perform and coordinate their respective services under this Agreement. Should one or more of such personnel become unavailable, Consultant may substitute other personnel of at least equal 14 | P a g e
competence upon written approval of City. If City and Consultant cannot agree as to the substitution of key personnel, City may terminate this Agreement for cause.

5.9. Permits and Approvals. Consultant shall obtain, at its sole cost and expense, all permits and regulatory approvals necessary for Consultant’s performance of this Agreement. This includes, but shall not be limited to, professional licenses, encroachment permits and building and safety permits and inspections.

5.10. Notification of Organizational Changes. Consultant shall notify the Agreement Administrator, in writing, of any change in name, ownership or control of Consultant’s firm or of any subcontractor. Change of ownership or control of Consultant’s firm may require an amendment to this Agreement.

5.11. Records. Consultant shall maintain any and all ledgers, books of account, invoices, vouchers, canceled checks, and other records or documents evidencing or relating to charges for services or expenditures and disbursements charged to City under this Agreement for a minimum of three (3) years, or for any longer period required by law, from the date of final payment to Consultant under this Agreement. All such documents shall be made available for inspection, audit, and/or copying at any time during regular business hours, upon oral or written request of City. In addition, pursuant to Government Code Section 8546.7, if the amount of public funds expended under this Agreement exceeds ten thousand dollars, all such documents and this Agreement shall be subject to the examination and audit of the State Auditor, at the request of City or as part of any audit of City, for a period of three (3) years after final payment under this Agreement.

6. SUBCONTRACTING

6.1. General Prohibition. This Agreement covers professional services of a specific and unique nature. Except as otherwise provided herein, Consultant shall not assign or transfer its interest in this Agreement or subcontract any services to be performed without amending this Agreement.

6.2. Consultant Responsible. Consultant shall be responsible to City for all services to be performed under this Agreement.

6.3. Identification in Fee Schedule. All subcontractors shall be specifically listed and their billing rates identified in the Approved Fee Schedule, Exhibit B. Any changes must be approved by the Agreement Administrator in writing as an amendment to this Agreement.
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7. COMPENSATION

7.1. General. City agrees to compensate Consultant for the services provided under this Agreement, and Consultant agrees to accept payment in accordance with the Fee Schedule in full satisfaction for such services. Compensation shall not exceed the Maximum Amount. Consultant shall not be reimbursed for any expenses unless provided for in this Agreement or authorized in writing by City in advance, such as via Task Orders

7.1.1. When City determines a need exists for any of the services specified in Exhibit A to this Agreement, City and Consultant may execute a “Task Order” detailing the specific services needed, the applicable fees therefor in accordance with Exhibit B to this Agreement, and the time for completion of such services by Consultant. Each Task Order shall be attached to this Agreement as a sequentially-identified Exhibit and thereby incorporated by reference. Consultant shall only perform services under this Agreement pursuant to a Task Order approved and executed by the City..

7.2. Invoices. Consultant shall submit to City an invoice, on a monthly basis or as otherwise agreed to by the Agreement Administrator, for services performed pursuant to this Agreement. Each invoice shall identify the Maximum Amount, the services rendered during the billing period, the amount due for the invoice, and the total amount previously invoiced. All labor charges shall be itemized by employee name and classification or position with the firm, the corresponding hourly rate, the hours worked, a description of each labor charge, and the total amount due for labor charges.

7.3. Taxes. City shall not withhold applicable taxes or other payroll deductions from payments made to Consultant except as otherwise required by law. Consultant shall be solely responsible for calculating, withholding, and paying all taxes.

7.4. Disputes. The parties agree to meet and confer at mutually agreeable times to resolve any disputed amounts contained in an invoice submitted by Consultant.

7.5. Additional Work. Consultant shall not be reimbursed for any expenses incurred for work performed outside the Scope of Services unless prior written approval is given by the City through a fully executed written amendment. Consultant shall not undertake any such work without prior written approval of the City.

7.6. City Satisfaction as Precondition to Payment. Notwithstanding any other terms of this Agreement, no payments shall be made to Consultant until City is satisfied that the services are satisfactory.
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7.7. Right to Withhold Payments. If Consultant fails to provide a deposit or promptly satisfy an indemnity obligation described in Section 11, City shall have the right to withhold payments under this Agreement to offset that amount.

8. PREVAILING WAGES
Consultant is aware of the requirements of California Labor Code Section 1720, et seq., and 1770, et seq., as well as California Code of Regulations, Title 8, Section 16000, et seq., (“Prevailing Wage Laws”), which require the payment of prevailing wage rates and the performance of other requirements on certain “public works” and “maintenance” projects including the design and preconstruction phases of a covered public works project. Consultant shall defend, indemnify, and hold the City, its elected officials, officers, employees, and agents free and harmless from any claim or liability arising out of any failure or alleged failure of Consultant to comply with the Prevailing Wage Laws.

9. OWNERSHIP OF WRITTEN PRODUCTS
All reports, documents or other written material, and all electronic files, including computeraided design files, developed by Consultant in the performance of this Agreement (such written material and electronic files are collectively known as “written products”) shall be and remain the property of City without restriction or limitation upon its use or dissemination by City except as provided by law. Consultant may take and retain copies of such written products as desired, but no such written products shall be the subject of a copyright application by Consultant.

10. RELATIONSHIP OF PARTIES

10.1. General. Consultant is, and shall at all times remain as to City, a wholly independent contractor.

10.2. No Agent Authority. Consultant shall have no power to incur any debt, obligation, or liability on behalf of City or otherwise to act on behalf of City as an agent. Neither City nor any of its agents shall have control over the conduct of Consultant or any of Consultant’s employees, except as set forth in this Agreement. Consultant shall not represent that it is, or that any of its agents or employees are, in any manner employees of City.

10.3. Independent Contractor Status. Under no circumstances shall Consultant or its employees look to the City as an employer. Consultant shall not be entitled to any benefits. City makes no representation as to the effect of this independent contractor relationship on Consultant’s previously earned California Public Employees Retirement System (“CalPERS”) retirement benefits, if any, and Consultant 17 | P a g e
specifically assumes the responsibility for making such a determination. Consultant shall be responsible for all reports and obligations including, but not limited to: social security taxes, income tax withholding, unemployment insurance, disability insurance, and workers’ compensation, and other applicable federal and state taxes.

10.4. Indemnification of CalPERS Determination. In the event that Consultant or any employee, agent, or subcontractor of Consultant providing services under this Agreement claims or is determined by a court of competent jurisdiction or CalPERS to be eligible for enrollment in CalPERS as an employee of the City, Consultant shall indemnify, defend, and hold harmless City for the payment of any employee and/or employer contributions for CalPERS benefits on behalf of Consultant or its employees, agents, or subcontractors, as well as for the payment of any penalties and interest on such contributions, which would otherwise be the responsibility of City.

11. INDEMNIFICATION

11.1. Definitions. For purposes of this Section 11, “Consultant” shall include Consultant, its officers, employees, servants, agents, or subcontractors, or anyone directly or indirectly employed by either Consultant or its subcontractors, in the performance of this Agreement. “City” shall include City, its officials, officers, agents, employees and volunteers.

11.2. Consultant to Indemnify City. Where the services to be provided by Consultant under this Agreement are design professional services, as that term is defined under Civil Code Section 2782.8, Consultant agrees to indemnify, defend and hold harmless, the City, its officers, officials, employees and volunteers from any and all claims, demands, costs or liability that actually or allegedly arise out of, or pertain to, or relate to the negligence, recklessness or willful misconduct of Consultant and its agents in the performance of services under this contract, but this indemnity does not apply to liability for damages for bodily injury, property damage or other loss, arising from the sole negligence, active negligence or willful misconduct by the City, its officers, official employees, and volunteers. If it is finally adjudicated that liability is caused by the comparative active negligence or willful misconduct of the City, then Consultant’s indemnification and defense obligations shall be reduced in proportion to the established comparative liability of the City and shall not exceed the Consultant’s proportionate percentage of fault.

As respects all acts or omissions which do not arise directly out of the performance of design professional services, including but not limited to those acts or omissions normally covered by general and automobile liability insurance, and to the full extent permitted by law, Consultant agrees to indemnity, defend and hold harmless the City, 18 | P a g e
its officers, officials, agents, employees, and volunteers from and against any claims, demands, losses, liability of any kind or nature (including liability for claims, suits, actions, arbitration proceedings, administrative proceedings, regulatory proceedings, losses, expenses or costs of any kind, whether actual, alleged or threatened, including attorney’s fees and costs, court costs, interest, defense costs, and expert witness fees) where the same arise out of, are in connection with, are a consequence of, or are in any way attributable to, in whole or in part, the performance of this Agreement by Consultant or by any individual or entity for which Consultant is legally liable, including but not limited to officers, agents, employees or sub-contractors of Consultant, excepting those which arise out of the active negligence, sole negligence or willful misconduct of the City, its officers, officials, employees and volunteers.

11.3. Scope of Indemnity. Personal injury shall include injury or damage due to death or injury to any person, whether physical, emotional, consequential or otherwise, Property damage shall include injury to any personal or real property. Consultant shall not be required to indemnify City for such loss or damage as is caused by the sole negligence, active negligence or willful misconduct of the City. If it is finally adjudicated that liability is caused by the comparative negligence or willful misconduct of an indemnified party, then Consultant’s indemnification obligation shall be reduced in proportion to the established comparative liability.

11.4. Attorneys’ Fees. Such costs and expenses shall include reasonable attorneys’ fees for counsel of City’s choice, expert fees and all other costs and fees of litigation.

Consultant shall not be entitled to any refund of attorneys’ fees, defense costs or expenses in the event that it is adjudicated to have been non-negligent.

11.5. Defense Deposit. The City may request a deposit for defense costs from Consultant with respect to a claim. If the City requests a defense deposit, Consultant shall provide it within 15 days of the request.

11.6. Waiver of Statutory Immunity. The obligations of Consultant under this Section 11 are not limited by the provisions of any workers’ compensation act or similar act.

Consultant expressly waives its statutory immunity under such statutes or laws as to City.

11.7. Indemnification by Subcontractors. Consultant agrees to obtain executed indemnity agreements with provisions identical to those set forth here in this Section 11 from each and every subcontractor or any other person or entity involved in the performance of this Agreement on Consultant’s behalf.

11.8. Insurance Not a Substitute. City does not waive any indemnity rights by accepting any insurance policy or certificate required pursuant to this Agreement. Consultant’s indemnification obligations apply regardless of whether or not any insurance policies 19 | P a g e
are determined to be applicable to the claim, demand, damage, liability, loss, cost or expense.

11.9. Civil Code. The parties are aware of the provisions of Civil Code 2782.8 relating to the indemnification and the duty and the cost to defend a public agency by a Design Professional and agree that this Section 11 complies therewith.

12. INSURANCE

12.1. Insurance Required. Consultant shall maintain insurance as described in this section and shall require all of its subcontractors, consultants, and other agents to do the same.

Approval of the insurance by the City shall not relieve or decrease any liability of Consultant. Any requirement for insurance to be maintained after completion of the work shall survive this Agreement.

12.2. Documentation of Insurance. City will not execute this agreement until it has received a complete set of all required documentation of insurance coverage. However, failure to obtain the required documents prior to the work beginning shall not waive the Consultant’s obligation to provide them. Consultant shall file with City:
 Certificate of Insurance, indicating companies acceptable to City, with a Best’s Rating of no less than A:VII showing. The Certificate of Insurance must include the following reference: [insert project name]
 Documentation of Best’s rating acceptable to the City.  Original endorsements effecting coverage for all policies required by this Agreement.
 Complete, certified copies of all required insurance policies, including endorsements affecting the coverage.

12.3. Coverage Amounts. Insurance coverage shall be at least in the following minimum amounts:
 Professional Liability Insurance: $2,000,000 per occurrence, $4,000,000 aggregate
 General Liability:
 General Aggregate: $4,000,000
 Products Comp/Op Aggregate $4,000,000
 Personal & Advertising Injury $2,000,000
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 Each Occurrence $2,000,000
 Fire Damage (any one fire) $ 100,000
 Medical Expense (any 1 person) $ 10,000
 Workers’ Compensation:
 Workers’ Compensation Statutory Limits
 EL Each Accident $1,000,000
 EL Disease – Policy Limit $1,000,000
 EL Disease – Each Employee $1,000,000
 Automobile Liability
 Any vehicle, combined single limit $1,000,000
Any available insurance proceeds broader than or in excess of the specified minimum insurance coverage requirements or limits shall be available to the City as additional insured. Furthermore, the requirements for coverage and limits shall be the greater of (1) the minimum coverage and limits specified in this Agreement, or (2) the broader coverage and maximum limits of coverage of any insurance policy or proceeds available to the named insured

12.4. General Liability Insurance. Commercial General Liability Insurance shall be no less broad than ISO form CG 00 01. Coverage must be on a standard Occurrence form.

Claims-Made, modified, limited or restricted Occurrence forms are not acceptable.

12.5. Worker’s Compensation Insurance. Consultant is aware of the provisions of Section 3700 of the Labor Code which requires every employer to carry Workers’ Compensation (or to undertake equivalent self-insurance), and Consultant will comply with such provisions before commencing the performance of the work of this Agreement. If such insurance is underwritten by any agency other than the State Compensation Fund, such agency shall be a company authorized to do business in the State of California.

12.6. Automobile Liability Insurance. Covered vehicles shall include owned if any, nonowned, and hired automobiles and, trucks.

12.7. Professional Liability Insurance or Errors & Omissions Coverage. The deductible or self-insured retention may not exceed $50,000. If the insurance is on a Claims-Made basis, the retroactive date shall be no later than the commencement of the work.

Coverage shall be continued for two years after the completion of the work by one of the following: (1) renewal of the existing policy; (2) an extended reporting period 21 | P a g e
endorsement; or (3) replacement insurance with a retroactive date no later than the commencement of the work under this Agreement.

12.8. Claims-Made Policies. If any of the required policies provide coverage on a claimsmade basis the Retroactive Date must be shown and must be before the date of the contract or the beginning of contract work. Claims-Made Insurance must be maintained and evidence of insurance must be provided for at least five (5) years after completion of the contract of work. If coverage is canceled or non-renewed, and not replaced with another claims-made policy form with a Retroactive Date prior to the contract effective date, the Consultant must purchase “extended reporting” coverage for a minimum of five (5) years after completion of contract work.

12.9. Additional Insured Endorsements. The City, its City Council, Commissions, officers, and employees of Lakeport must be endorsed as an additional insured for each policy required herein, other than Professional Errors and Omissions, for liability arising out of ongoing and completed operations by or on behalf of the Consultant.

Consultant’s insurance policies shall be primary as respects any claims related to or as the result of the Consultant’s work. Any insurance, pooled coverage or self-insurance maintained by the City, its elected or appointed officials, directors, officers, agents, employees, volunteers, or consultants shall be non-contributory. All endorsements shall be signed by a person authorized by the insurer to bind coverage on its behalf. General liability coverage can be provided using an endorsement to the Consultant’s insurance at least as broad as ISO Form CG 20 10 11 85 or both CG 20 10 and CG 20 37.

12.10. Failure to Maintain Coverage. In the event any policy is canceled prior to the completion of the project and the Consultant does not furnish a new certificate of insurance prior to cancellation, City has the right, but not the duty, to obtain the required insurance and deduct the premium(s) from any amounts due the Consultant under this Agreement. Failure of the Consultant to maintain the insurance required by this Agreement, or to comply with any of the requirements of this section, shall constitute a material breach of this Agreement.

12.11. Notices. Contractor shall provide immediate written notice if (1) any of the required insurance policies is terminated; (2) the limits of any of the required policies are reduced; (3) or the deductible or self-insured retention is increased. Consultant shall provide no less than 30 days’ notice of any cancellation or material change to policies required by this Agreement. Consultant shall provide proof that cancelled or expired policies of insurance have been renewed or replaced with other policies providing at least the same coverage. Such proof will be furnished at least two weeks prior to the expiration of the coverages. The name and address for Additional Insured Endorsements, Certificates of Insurance and Notices of Cancellation is: City of 22 | P a g e
Lakeport, Attn: [insert department or individual], 225 Park Street, Lakeport, California 95453.

12.12. Consultant’s Insurance Primary. The insurance provided by Consultant, including all endorsements, shall be primary to any coverage available to City. Any insurance or self-insurance maintained by City and/or its officers, employees, agents or volunteers, shall be in excess of Consultant’s insurance and shall not contribute with it.

12.13. Waiver of Subrogation. Consultant hereby waives all rights of subrogation against the City. Consultant shall additionally waive such rights either by endorsement to each policy or provide proof of such waiver in the policy itself. Consultant agrees to obtain any endorsement that may be necessary to affect this waiver of subrogation, but this provision applies regardless of whether or not the City has received a waiver of subrogation endorsement from the insurer. However, the Workers’ Compensation policy shall be endorsed with a waiver of subrogation in favor of the City for all work performed by the Consultant, its employees, agents and subcontractors.

12.14. Report of Claims to City. Consultant shall report to the City, in addition to the Consultant’s insurer, any and all insurance claims submitted to Consultant’s insurer in connection with the services under this Agreement.

12.15. Premium Payments and Deductibles. Consultant must disclose all deductibles and self-insured retention amounts to the City. The City may require the Consultant to provide proof of ability to pay losses and related investigations, claim administration, and defense expenses within retention amounts. Ultimately, City must approve all such amounts prior to execution of this Agreement. City has no obligation to pay any premiums, assessments, or deductibles under any policy required in this Agreement.

Consultant shall be responsible for all premiums and deductibles in all of Consultant’s insurance policies. The amount of deductibles for insurance coverage required herein are subject to City’s approval.

12.16. Duty to Defend and Indemnify. Consultant’s duties to defend and indemnify City under this Agreement shall not be limited by the foregoing insurance requirements and shall survive the expiration of this Agreement.

13. MUTUAL COOPERATION

13.1. City Cooperation in Performance. City shall provide Consultant with all pertinent data, documents and other requested information as is reasonably available for the proper performance of Consultant’s services under this Agreement. 23 | P a g e

13.2. Consultant Cooperation in Defense of Claims. If any claim or action is brought against City relating to Consultant’s performance in connection with this Agreement, Consultant shall render any reasonable assistance that City may require in the defense of that claim or action.

14. NOTICES
Any notices, bills, invoices, or reports required by this Agreement shall be deemed received on: (i) the day of delivery if delivered by hand, facsimile or overnight courier service during Consultant’s and City’s regular business hours; or (ii) on the third business day following deposit in the United States mail if delivered by mail, postage prepaid, to the addresses listed below (or to such other addresses as the parties may, from time to time, designate in writing).

If to City
[Name]
City of Lakeport
Public Works/Engineering
225 Park Street
Lakeport, CA 95453
Telephone: (707) 263-5615
Facsimile: (707) 263-8584
If to Consultant
[Name]
[Address]
[Address]
Telephone:

Facsimile:

With courtesy copy to:

David J. Ruderman, Esq.

Lakeport City Attorney
Colantuono, Highsmith & Whatley, PC
420 Sierra College Drive, Suite 140
Grass Valley, CA 95945
Telephone: (530) 432-7357
Facsimile: (530) 432-7356

15. SURVIVING COVENANTS
The parties agree that the covenants contained in paragraph 6.11 (Records), paragraph 11.4 (Indemnification of CalPERS Determination), Section 12 (Indemnity), paragraph 13.8 (ClaimsMade Policies), paragraph 14.2 (Consultant Cooperation in Defense of Claims), and paragraph

19.1 (Confidentiality) of this Agreement shall survive the expiration or termination of this Agreement, subject to the provisions and limitations of this Agreement and all otherwise applicable statutes of limitations and repose.
24 | P a g e

16. TERMINATION

16.1. City Termination. City may terminate this Agreement for any reason on five calendar days’ written notice to Consultant. Consultant agrees to cease all work under this Agreement on or before the effective date of any notice of termination. All City data, documents, objects, materials or other tangible things shall be returned to City upon the termination or expiration of this Agreement.

16.2. Consultant Termination. Consultant may terminate this Agreement for a material breach of this Agreement upon 30 days’ notice.

16.3. Compensation Following Termination. Upon termination, Consultant shall be paid based on the work satisfactorily performed at the time of termination. In no event shall Consultant be entitled to receive more than the amount that would be paid to Consultant for the full performance of the services required by this Agreement. The City shall have the benefit of such work as may have been completed up to the time of such termination.

16.4. Remedies. City retains any and all available legal and equitable remedies for Consultant’s breach of this Agreement.

17. INTERPRETATION OF AGREEMENT

17.1. Governing Law. This Agreement shall be governed and construed in accordance with the laws of the State of California.

17.2. Integration of Exhibits. All documents referenced as exhibits in this Agreement are hereby incorporated into this Agreement. In the event of any material discrepancy between the express provisions of this Agreement and the provisions of any document incorporated herein by reference, the provisions of this Agreement shall prevail. This instrument contains the entire Agreement between City and Consultant with respect to the transactions contemplated herein. No other prior oral or written agreements are binding upon the parties. Amendments hereto or deviations herefrom shall be effective and binding only if made in writing and executed on by City and Consultant.

17.3. Headings. The headings and captions appearing at the commencement of the sections hereof, and in any paragraph thereof, are descriptive only and for convenience in reference to this Agreement. Should there be any conflict between such heading, and the section or paragraph thereof at the head of which it appears, the language of the section or paragraph shall control and govern in the construction of this Agreement. 25 | P a g e

17.4. Pronouns. Masculine or feminine pronouns shall be substituted for the neuter form and vice versa, and the plural shall be substituted for the singular form and vice versa, in any place or places herein in which the context requires such substitution(s).

17.5. Severability. If any term or provision of this Agreement or the application thereof to any person or circumstance shall, to any extent, be invalid or unenforceable, then such term or provision shall be amended to, and solely to the extent necessary to, cure such invalidity or unenforceability, and shall be enforceable in its amended form. In such event, the remainder of this Agreement, or the application of such term or provision to persons or circumstances other than those as to which it is held invalid or unenforceable, shall not be affected, and each term and provision of this Agreement shall be valid and be enforced to the fullest extent permitted by law.

17.6. No Presumption Against Drafter. Each party had an opportunity to consult with an attorney in reviewing and drafting this agreement. Any uncertainty or ambiguity shall not be construed for or against any party based on attribution of drafting to any party.

18. GENERAL PROVISIONS

18.1. Confidentiality. All data, documents, discussion, or other information developed or received by Consultant for performance of this Agreement are deemed confidential and Consultant shall not disclose it without prior written consent by City. City shall grant such consent if disclosure is legally required. All City data shall be returned to City upon the termination or expiration of this Agreement.

18.2. Conflicts of Interest. Consultant maintains and warrants that it has not employed nor retained any company or person, other than a bona fide employee working solely for Consultant, to solicit or secure this Agreement. Further, Consultant warrants that it has not paid nor has it agreed to pay any company or person, other than a bona fide employee working solely for Consultant, any fee, commission, percentage, brokerage fee, gift or other consideration contingent upon or resulting from the award or making of this Agreement. Consultant further agrees to file, or shall cause its employees or subcontractor to file, a Statement of Economic Interest with the City’s Filing Officer if required under state law in the performance of the services. For breach or violation of this warranty, City shall have the right to rescind this Agreement without liability. For the term of this Agreement, no member, officer, or employee of City, during the term of his or her service with City, shall have any direct interest in this Agreement, or obtain any present or anticipated material benefit arising therefrom. 26 | P a g e

18.3. Non-assignment. Both parties shall not delegate, transfer, subcontract or assign its duties or rights hereunder, either in whole or in part, without the other party’s prior written consent, and any attempt to do so shall be void and of no effect. City shall not be obligated or liable under this Agreement to any party other than Consultant.

18.4. Binding on Successors. This Agreement shall be binding on the successors and assigns of the parties.

18.5. No Third-Party Beneficiaries. Except as expressly stated herein, there is no intended third-party beneficiary of any right or obligation assumed by the parties.

18.6. Time of the Essence. Time is of the essence for each and every provision of this Agreement.

18.7. Non-Discrimination. Consultant shall not discriminate against any employee or applicant for employment because of race, sex (including pregnancy, childbirth, or related medical condition), creed, national origin, color, disability as defined by law, disabled veteran status, Vietnam veteran status, religion, age (40 and above), medical condition (cancer-related), marital status, ancestry, or sexual orientation. Employment actions to which this provision applies shall include, but not be limited to, the following: employment, upgrading, demotion, or transfer; recruitment or recruitment advertising; layoff or termination; rates of pay or other forms of compensation; or in terms, conditions or privileges of employment, and selection for training. Consultant agrees to post in conspicuous places, available to employees and applicants for employment, the provisions of this nondiscrimination clause.

18.8. Waiver. No provision, covenant, or condition of this Agreement shall be deemed to have been waived by City or Consultant unless in writing signed by one authorized to bind the party asserted to have consented to the waiver. The waiver by City or Consultant of any breach of any provision, covenant, or condition of this Agreement shall not be deemed to be a waiver of any subsequent breach of the same or any other provision, covenant, or condition.

18.9. Excused Failure to Perform. Consultant shall not be liable for any failure to perform if Consultant presents acceptable evidence, in City’s sole judgment, that such failure was due to causes beyond the control and without the fault or negligence of Consultant.

18.10. Remedies Non-Exclusive. Each right, power and remedy provided for herein or now or hereafter existing at law, in equity, by statute, or otherwise shall be cumulative and shall be in addition to every other right, power, or remedy provided for herein or now 27 | P a g e
or hereafter existing at law, in equity, by statute, or otherwise. The exercise, the commencement of the exercise, or the forbearance from the exercise by any party of any one or more of such rights, powers or remedies shall not preclude the simultaneous or later exercise by such party of any or all of such other rights, powers or remedies.

18.11. Attorneys’ Fees. In the event of a dispute arising out of the terms of this Agreement, including any action brought to declare the rights granted herein or to enforce any of the terms of this Agreement, the party prevailing in such dispute shall be entitled to all reasonable costs and litigation expenses actually incurred, including fees of attorneys and expert witnesses.

18.12. Venue. The venue for any litigation shall be Lake County, California and Consultant hereby consents to jurisdiction in Lake County for purposes of resolving any dispute or enforcing any obligation arising under this Agreement.

18.13. Counterparts; Electronic Signatures. This Agreement may be signed in one or more counterparts, each of which shall be deemed an original, but all of which together shall be deemed one and the same instrument. The parties acknowledge and agree that this Agreement may be executed by electronic signature, which shall be considered as an original signature for all purposes and shall have the same force and effect as an original signature. Without limitation, “electronic signature” shall include faxed or emailed versions of an original signature, electronically scanned and transmitted versions (e.g., via pdf) of an original signature, or a digital signature. [Signatures on following page]

28 | P a g e
TO EFFECTUATE THIS AGREEMENT, the parties have caused their duly authorized representatives to execute this Agreement on the dates set forth below. “City”
City of Lakeport
By:________________________________
Signature
Printed:_____________________________
Title:_______________________________
Date:______________________
“Consultant”
[Name of Company or Individual]
By:________________________________
Signature
Printed:_____________________________
Title:_______________________________
Date:______________________
Attest:

By:__________________________________
Kelly Buendia, City Clerk
Date:________________________
By:________________________________
Signature
Printed:_____________________________
Title:_______________________________
Date:______________________
Approved as to form:

By:__________________________________
David J. Ruderman, City Attorney

Date:________________________

29 | P a g e
Professional Services Agreement
City of Lakeport / (Consultant)
386151.1 Page 1 of 1
262868.2
AMENDMENT No. # 1 TO PROFESSIONAL SERVICES AGREEMENT FOR

DESIGN PROFESSIONAL
(City of Lakeport and (Consultant))
This Amendment No. #1 (“Amendment”) to Professional Services Agreement dated October 19, 2022 (“Agreement”) is made on this 14th day of October 2025 at Lakeport, California, by and between the City of Lakeport, a municipal corporation, 225 Park Street, Lakeport, California 95453 (“City”) and (Consultant), (Consultant Address)(“Consultant”).

This Amendment modifies the original Agreement between the City and the Consultant dated October 20, 2022 in the following fashion:

A. City and Consultant desire to amend the Agreement by modifying section 3.7 – Termination Date of the Agreement to read as follows:

3.7 “Termination Date”: October 20, 2026.

B. Except as modified herein, the terms of that Agreement dated October 20, 2022, shall remain in full force and effect.

TO EFFECTUATE THIS AMENDMENT NO. 1, the parties have caused their duly authorized representatives to execute this Amendment No. 1 as of the day and year first written above.
“City”
City of Lakeport
By: ______________________________
Signature
Attest:

By: ______________________________
Kelly Buendia, City Clerk
Date: ____________
“Consultant”
(Consultant)
By:______________________________
Signature

By:______________________________
Signature

Meeting Date: 10/21/2025 Page 1 Agenda Item #VII.B.1

CITY OF LAKEPORT
City Council ☒
City of Lakeport Municipal Sewer District ☒
Lakeport Industrial Development Authority ☒
Municipal Financing Agency of Lakeport ☒

STAFF REPORT
RE: Amendment to FY 25/26 Budget MEETING DATE: 10/21/2025 SUBMITTED BY: Danielle Dizon, Finance Director
PURPOSE OF REPORT: ☐Information only ☐ Discussion ☒Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

The City Council is being asked to adopt a resolution approving an amendment to the annual budget for fiscal year 2025/26 to authorize the transfer and appropriation of unreserved fund balance in order to perform necessary storm drainage improvements on Tenth Street.

BACKGROUND/DISCUSSION:

It has been determined that storm drainage improvements are necessary to be completed on Tenth Street in the current fiscal year. Funds have been identified as unreserved fund balance in fund 401 (Tenth St Drainage) that have been accumulating for this purpose. It is now prudent to transfer those funds into the Storm Drainage Fund (414) to complete that work and classify the expenditures in a consistent manner with other storm drainage activities.

The proposed resolution includes the transfer of these accumulated funds, in the amount of $87,086.72, from fund 401 to 414 and appropriate them for use in a capital asset account for future capitalization of the infrastructure improvements.

OPTIONS:

1. Approve the proposed Resolution to amend the annual budget for fiscal year 2025/26.

2. Do not approve and provide alternative direction to staff.

FISCAL IMPACT:
☐ None ☐ $87,086.72 Budgeted Item? ☐Yes ☒ No
Budget Adjustment Needed? ☒Yes ☐ No If yes, amount of appropriation increase: $87,086.72 Affected fund(s): ☐ General Fund ☐ Water OM Fund ☐ Sewer OM Fund ☐ Other: 401, 414 Comments:

COUNCIL PRIORITIES:
☐ Priority #1: Public Safety & Crisis Response
Meeting Date: 10/21/2025 Page 2 Agenda Item #VII.B.1
☐ Priority #2: Disaster Resiliency
☒ Priority #3: Good Governance & Fiscal Stability
☒ Priority #4: Capital Infrastructure Improvement
☒ Priority #5: Safe, Sustainable & Attractive Neighborhoods ☐ Priority #6: Economic Development
SUGGESTED MOTIONS:

Move to adopt the resolution to amend the annual budget for fiscal year 2025/26 to authorize the transfer and appropriation of unreserved fund balance.
☒ Attachments: 1. Budget Amendment Resolution
418370.1
RESOLUTION NO. XXXXX (2025)

A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF LAKEPORT, THE SUCCESSOR

AGENCY TO THE LAKEPORT REDEVELOPMENT AGENCY, AND THE BOARD OF THE

CITY OF LAKEPORT MUNICIPAL SEWER DISTRICT APPROVING AN AMENDMENT TO THE ANNUAL BUDGET FOR FISCAL YEAR 2025-26 TO AUTHORIZE THE TRANSFER AND

APPROPRIATION OF UNRESERVED FUND BALANCE
WHEREAS, on June 30, 2025, the City Council approved and adopted the Annual Budget for Fiscal Year (FY) 2025-26; and
WHEREAS, the City Council finds that an adjustment to the Annual Budget for FY 2025-26 is necessary and desirable to transfer and appropriate unreserved fund balance for use and that this adjustment would be fiscally responsible, consistent with City priorities, and would not compromise the City’s ability to respond to future emergencies or obligations; and WHEREAS, the City Council of the City of Lakeport has held a duly noticed meeting to review and provide opportunity for and receive public comments regarding the proposed amendment to the Annual Budget for FY 2025-26.

NOW, THEREFORE, BE IT RESOLVED that the City Council of the City of Lakeport hereby approves an amendment to the adopted Budget for FY 2025–26 to authorize to transfer and appropriate unreserved fund balance for use. The City’s Finance Director is hereby authorized to make the following adjustments:

Fund Fund Title Dept Account Amount
401 TENTH ST DRAINAGE 0000 Fund Balance $ (87,086.72)
401 TENTH ST DRAINAGE 0000 991000 - Transfers Out $ 87,086.72 414 STORM DRAINAGE 0000 790000 - Transfer In $ (87,086.72) 414 STORM DRAINAGE 3020 990000 - Land, Structure, Imp $ 87,086.72 PASSED, RESOLVED, AND ADOPTED, at a Regular Meeting of the City Council of the City of Lakeport, held on this 21ST day of October 2025, by the following vote:

AYES:

NOES:

ABSTAIN:

ABSENT:
________________________________
Kim Costa, Mayor
ATTEST:
________________________________
Kelly Buendia, City Clerk
Meeting Date: 10/21/2025 Page 1 Agenda Item #VII.B.2

CITY OF LAKEPORT
City Council ☒
City of Lakeport Municipal Sewer District ☐
Lakeport Industrial Development Authority ☐
Municipal Financing Agency of Lakeport ☐

STAFF REPORT
RE: Fourth Quarter Update, FY 2024/25 MEETING DATE: 10/21/25 SUBMITTED BY: Danielle Dizon, Finance Director
PURPOSE OF REPORT: ☒Information only ☐ Discussion ☐Action Item WHAT IS BEING ASKED OF THE CITY COUNCIL/BOARD:

The City Council is being asked to review and file the 4th Quarter 24/25 Financial Update.

BACKGROUND/DISCUSSION:

Financial Update
Attachment A to this staff report includes summarized unaudited financial statements for the general fund, water operating and maintenance fund, and the sewer operating and maintenance fund, which include revenue and expense activity through June 30, 2025. The format in which the statements are prepared is similar to the annual budget. The schedule includes amounts available for discretionary spending for each fund anticipated to be presented in the 2024-25 audited financial statements, in accordance with Generally Accepted Accounting Principles (GAAP), as well as the amounts of anticipated ending discretionary spending expected to be available at the 2024-25 year-end. In the enterprise funds, the term “working capital” is defined as current assets minus current liabilities. For budgeting purposes, the modified accrual method is used and this is common practice among governmental agencies. Working capital is the enterprise funds equivalent of the general funds amounts available for discretionary spending.

In accordance with GAAP, financial statements in the Annual Comprehensive Financial Report (ACFR) are presented in two distinctly different ways, (1) the governmental fund financial statements and (2) government wide and enterprise fund financial statements. Governmental fund financial statements present balances using a current financial resources measurement focus which emphasizes the current available spendable resources available for appropriation. This method of accounting is known as modified accrual. Government wide and enterprise fund financial statements are presented on a flow of economic resources measurement focus which reports all assets and liabilities whether current or long term. This method is referred to as accrual accounting and is similar to the type of presentation that is used in private industry.

Meeting Date: 10/21/2025 Page 2 Agenda Item #VII.B.2
Investments
According to the idle funds investment policy for the City of Lakeport, the City of Lakeport Municipal Sewer District (CLMSD) and Municipal Financing Agency of Lakeport (MFAL), quarterly updates are to be provided to the City Council for review.

This schedule provides detailed information on each individual CD as of June 30, 2025:

This schedule provides balances and concentration percentages of the City-wide cash and investment balances as of June 30, 2025:

OPTIONS:

1. Review and file the 4th Quarter Financial Update.

2. Do not review and file but provide direction to staff.

Meeting Date: 10/21/2025 Page 3 Agenda Item #VII.B.2
FISCAL IMPACT:
☒ None ☐ $ Budgeted Item? ☐Yes ☐ No
Budget Adjustment Needed? ☐Yes ☒ No If yes, amount of appropriation increase: $ Affected fund(s): ☐ General Fund ☐ Water OM Fund ☐ Sewer OM Fund ☐ Other:

Comments:

NONE.
☐ Attachments:

Summarized unaudited financial statements for the general fund, water operating and maintenance fund and the sewer operating and maintenance fund.

Fund: 110
Name: General Fund
2024-25 2024-25
Adjusted Budget As of June 30, 2025 Remaining $ % Collected/ Used
Taxes $ 5,582,223 $ 5,994,522 $ (412,299) 107%
Franchises 336,000 356,916 (20,916) 106%
Licenses 200 270 (70) 135%
Permits 107,500 161,682 (54,182) 150%
Fines, forfeitures, and penalties 11,000 8,900 2,100 81% Use of money and property 87,000 265,372 (178,372) 305% Income from other agencies 179,000 97,537 81,463 54%
Federal funding 1,000 1,673 (673) 167%
State funding 202,500 164,226 38,274 81%
Charges for service 90,000 188,194 (98,194) 209%
Other revenue 74,300 247,138 (172,838) 333%
Total revenue 6,670,723 7,486,430 (815,707) 112%
4,023,997 3,751,638 272,359 93%
2,273,803 2,205,657 68,146 97%
248,961 227,123 21,838 91%
Total expenditures 6,546,761 6,184,418 362,343 94%
Use of fund balance - -
45,000 44,694
(455,830) (452,925)
Net sources (uses) (410,830) (408,231)
Resources - Use
Surplus (deficit) $ (286,868) $ 893,781
Beginning General Fund Balance 6,791,513 6,791,513
Nonspendable (289,481) (289,481)
Restricted (24,462) (24,462)
Operating Reserve (990,465) (990,465)
Reserve for Economic Uncertainties (1,320,619) (1,320,619) VERF (177,735) (177,735)
RIMF (284,509) (284,509)
PORF (1,068,337) (1,068,337)
Compensated Absences (427,848) (427,848)
Beginning Discretionary General Fund Balance 2,208,057 2,208,057 Inflows 6,715,723 7,531,124
Outflows 7,002,591 6,637,343
(286,868) 893,781
Anticipated Ending Discretionary General Fund Balance $ 1,921,189 $ 3,101,838 Adjusted Budget As of June 30, 2025
Non-Departmental 772,832 828,552 (55,720) 107%
Legislative 140,132 125,669 14,463 90%
Administration 457,796 416,165 41,631 91%
Economic Development 151,500 72,307 79,193 48%
City Attorney 50,000 67,607 (17,607) 135%
Finance and Information Technology 417,664 439,274 (21,610) 105% Community Development:

Planning 413,907 340,432 73,475 82%
Building 418,328 364,641 53,687 87%
Engineering 172,844 176,454 (3,610) 102%
Police 2,888,229 2,624,023 264,206 91%
Public Works:

Administration and Compliance 137,787 143,965 (6,178) 104% Roads and Infrastructure 564,955 570,985 (6,030) 101%
Parks, Buildings, and Grounds 416,617 467,268 (50,651) 112% Total use 7,002,591 6,637,342 365,249 95%
Departmental Use
Expenditures
Change to fund balance
Fiscal Year 2024-25
Financing Sources (Uses)
Transfers in
Transfers (out)
Revenue Sources
Salaries and benefits
Operations
Capital outlay/CIP
Fund: 501
Name: Water Utility M & O Fund
2024-25 2024-25
Adjusted Budget As of June 30, 2025 Remaining $ % Collected/ Used
Charges for service 2,937,000 2,937,192 (192) 100%
Interfund services provided 120,000 110,918 9,082 92%
Total revenue 3,057,000 3,088,070 (31,070) 101%
-
1,378,352 1,375,615 2,737 100%
798,322 882,525 (84,203) 111%
Debt service 756,068 613,790 142,278 81%
6,179,914 4,712,768 1,467,146 76%
Total expenditures 9,112,656 7,584,698 1,527,958 83%
-
Net sources (uses) - - -
Resources - Use -
Surplus (deficit) (6,055,656) (4,496,628)
Beginning Working Capital 6,782,156 6,782,156
Inflows 3,057,000 3,088,070
Outflows 9,112,656 7,584,698
Change to fund balance (6,055,656) (4,496,628)
Anticipated Ending Working Capital $ 726,500 $ 2,285,528 Adjusted Budget As of June 30, 2025
Non-Departmental 826,068 727,484 98,584 88%
Legislative 19,000 19,874 (874) 105%
Administration 151,569 130,128 21,441 86%
City Attorney 28,000 41,488 (13,488) 148%
Finance and Information Technology 331,850 339,202 (7,352) 102% Community Development: -
Planning 25,446 22,842 2,604 90%
Building 32,581 34,621 (2,040) 106%
Engineering 70,987 77,062 (6,075) 109%
Public Works: -
Administration and Compliance 216,871 187,146 29,725 86% Water O&M 7,410,284 6,004,850 1,405,434 81%
Total use 9,112,656 7,584,697 1,527,959 83%
Departmental Use
Financing Sources (Uses)
Fiscal Year 2024-25
Revenue Sources
Expenditures
Salaries and benefits
Operations
Capital outlay/CIP
Fund: 601
Name: Sewer Utility M & O Fund
2024-25 2024-25
Adjusted Budget As of June 30, 2025 Remaining $ % Collected/ Used
Taxes $ 55,050 $ 86,474 $ (31,424) 157%
Use of money and property 52,500 106,418 (53,918) 203%
Charges for service 3,130,000 3,513,161 (383,161) 112%
Interfund services provided 18,000 22,188 (4,188) 123%
Total revenue 3,255,550 3,728,864 (473,314) 115%
1,379,852 1,363,941 15,911 99%
1,071,526 1,480,471 (408,945) 138%
Debt service 686,228 636,399 49,829 93%
3,974,001 3,396,531 577,470 85%
Total expenditures 7,111,607 6,877,342 234,265 97%
Net sources (uses) - -
Resources - Use
Surplus (deficit) (3,856,057) (3,148,478)
Audited Beginning Working Capital 5,933,190 5,933,190
Inflows 3,255,550 3,728,864
Outflows 7,111,607 6,877,342
Change to fund balance (3,856,057) (3,148,478)
Anticipated Ending Working Capital $ 2,077,133 $ 2,784,712 Adjusted Budget As of June 30, 2025
Non-Departmental 756,228 750,597 5,631 99%
Legislative 19,000 21,164 (2,164) 111%
Administration 152,159 130,128 22,031 86%
City Attorney 28,000 39,276 (11,276) 140%
Finance and Information Technology 325,750 333,526 (7,776) 102% Community Development:

Planning 25,446 22,842 2,604 90%
Building 32,581 34,825 (2,244) 107%
Engineering 70,987 77,061 (6,074) 109%
Public Works:

Administration and Compliance 216,871 187,143 29,728 86% Sewer O&M 5,484,585 5,280,779 203,806 96%
Total use 7,111,607 6,877,341 234,266 97%
Fiscal Year 2024-25
Revenue Sources
Departmental Use
Financing Sources (Uses)
Expenditures
Salaries and benefits
Operations
Capital outlay/CIP

Lakeport City CouncilOctober 21, 2025

Lakeport City Council
October 21, 2025