Agenda packet — San Diego Community Power Board of Directors, January 20, 2022

AGENDA – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 1 AGENDA
Special Meeting of the Board of Directors of
San Diego Community Power (SDCP)
January 20, 2022
4:00 p.m.

There will be no location for in-person attendance. In compliance with the Brown Act, SDCP is providing alternatives to in-person attendance for viewing and participating in the meeting. Further details are below.

Note: Any member of the public may provide comments to the Board of Directors on any agenda item. When providing comments to the Board, it is requested that you provide your name and city of residence for the record. Commenters are requested to address their comments to the Board as a whole through the Chair. Comments may be provided in one of the following manners:

1. Providing Oral Comments During Meeting. To provide comments during the meeting, join the Zoom meeting by computer, mobile phone, or dial-in number. On Zoom video conference by computer or mobile phone, use the “Raise Hand” feature. This will notify the moderator that you wish to speak during a specific item on the agenda or during non-agenda Public Comment.

Members of the public will not be shown on video but will be able to speak when called upon.

If joining the meeting using the Zoom dial-in number, you can raise your hand by pressing *9.

Comments will be limited to three (3) minutes. Please be aware that the Chair has the authority to reduce equally each speaker's time to accommodate a large number of speakers.

2. Written Comments. Written public comments must be submitted prior to the start of the meeting by using this (web form). Please indicate a specific agenda item when submitting your comment. All written comments received prior to the meeting will be provided to the Board members in writing. In the discretion of the Chair, the first ten (10) submitted comments shall be stated into the record of the meeting. Comments read at the meeting will be limited to the first 400 words. Comments received after the start of the meeting will be collected, sent to the Board members in writing, and be part of the public record.

If you have anything that you wish to be distributed to the Board, please provide it via [email protected] and it will be distributed to the Members.

The public may participate using the following remote options:

ACTION ITEM

1. Approval of Findings to Continue Holding Remote/Teleconference Meetings Pursuant to Assembly Bill 361
Recommendation: Find and determine that the Board has reconsidered the circumstances of the COVID-19 State of Emergency; the State of Emergency remains in effect; state or local officials continue to impose or recommend social distancing measures; and meetings of SDCP legislative bodies may be held remotely in compliance with Government Code section 54953(e) for the next 30 days.

PUBLIC COMMENTS ON CLOSED SESSION ITEMS

CLOSED SESSION

2. PUBLIC EMPLOYEE APPOINTMENT PURSUANT TO GOVERNMENT CODE SECTION 54957
Title: Chief Executive Officer

3. CONFERENCE WITH LABOR NEGOTIATORS PURSUANT TO GOVERNMENT CODE SECTION 54957.6
Agency designated representative(s): Cindy Krebs, Alliance Resource Consulting Unrepresented employee: Chief Executive Officer

REPORT FROM CLOSED SESSION

ADJOURNMENT
Compliance with the Americans with Disabilities Act
SDCP Board of Directors meetings comply with the protections and prohibitions of the Americans with Disabilities Act. Individuals with a disability who require a modification or accommodation, including auxiliary aids or services, in order to participate in the public meeting may contact (888) 382-0169 or [email protected]. Requests for disability-related modifications or accommodations require different lead times and should be provided at least 72-hours in advance of the public meeting.

Availability of Board Documents
Copies of the agenda and agenda packet are available at https://sdcommunitypower.org/resources/meeting-notes/. Late-arriving documents related to a Board meeting item which are distributed to a majority of the Members prior to or during the Board meeting are available for public review as required by law. Previously, public records were available for inspection at the City of San Diego Sustainability Department, located at 1200 Third Ave., Suite 1800, San Diego, CA 92101. However, due to the Governor’s Executive Orders N-25- AGENDA – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 3 20 and N-29-20 and the need for social distancing, in-person inspection is now suspended. Public records, including agenda-related documents, can instead be requested electronically at [email protected] or by mail to SDCP, 815 E Street, Suite 12716, San Diego, CA 92112. The documents may also be posted at the above website.

AGENDA – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 1 AGENDA
Regular Meeting of the Board of Directors of
San Diego Community Power (SDCP)
January 20, 2022
5:00 p.m.

The meeting will proceed as a teleconference meeting in compliance with waivers to certain provisions of the Brown Act provided for under Government Code section 54953(e)(1)(A), in relation to the COVID-19 State of Emergency and recommended social distancing measures. There will be no location for in-person attendance. In compliance with the Brown Act, SDCP is providing alternatives to in-person attendance for viewing and participating in the meeting. Further details are below.

Note: Any member of the public may provide comments to the Board of Directors on any agenda item.

When providing comments to the Board, it is requested that you provide your name and city of residence for the record. Commenters are requested to address their comments to the Board as a whole through the Chair. Comments may be provided in one of the following manners:

Members of the public will not be shown on video but will be able to speak when called upon. If joining the meeting using the Zoom dial-in number, you can raise your hand by pressing *9.

Comments will be limited to three (3) minutes. Please be aware that the Chair has the authority to reduce equally each speaker's time to accommodate a large number of speakers.

2. Written Comments. Written public comments must be submitted prior to the start of the meeting by using this (web form). Please indicate a specific agenda item when submitting your comment.

All written comments received prior to the meeting will be provided to the Board members in writing. In the discretion of the Chair, the first ten (10) submitted comments shall be stated into the record of the meeting. Comments read at the meeting will be limited to the first 400 words.

Comments received after the start of the meeting will be collected, sent to the Board members in writing, and be part of the public record.

If you have anything that you wish to be distributed to the Board, please provide it via [email protected] and it will be distributed to the Members.

The public may participate using the following remote options:

Teleconference Meeting Webinar https://zoom.us/j/94794075133 Telephone (Audio Only) (669) 900-6833 or (346) 248-7799 | Webinar ID: 947 9407 5133 AGENDA – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 2 Welcome
Call to Order
Pledge of Allegiance
Ceremonial Oath of Office
Roll Call
Report from Closed Session
Items to be Added, Withdrawn, or Reordered on the Agenda Public Comments
Opportunity for members of the public to address the Board on any items not on the agenda but within the jurisdiction of the Board. Members of the public may provide a comment in either manner described above.

Consent Calendar
All matters are approved by one motion without discussion unless a member of the Board of Directors requests a specific item to be removed from the Consent Agenda for discussion. A member of the public may comment on any item on the Consent Calendar in either manner described above.

1. Approval of September 23, 2021 Meeting Minutes

2. Receive and File Treasurer’s Report for Period Ending 11/30/2021

3. Receive and File 6/30/21 Fiscal Year End Audited Financial Statement

4. Appointment of Director LaCava to the Finance and Risk Management Committee

5. Update on Back Office Metrics/Dashboard

6. Update on Regulatory and Legislative Affairs

7. Update on Community Advisory Committee

8. Update on Residential Enrollment Public Relations

REGULAR AGENDA
The following items call for discussion or action by the Board of Directors. The Board may discuss and/or take action on any item listed below if the Board is so inclined.

9. Election of Chair and Vice Chair for Calendar Year 2022 Recommendation: Elect a Chair and Vice Chair for Calendar Year 2022.

10. Approval of 2022 Rates
Recommendation: Approve the rates contained in Attachment A to be effective as of February 1, 2022.

AGENDA – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 3 11. Update on CEO Search Ad Hoc Committee Efforts
Recommendation: Provide update on CEO Search Ad Hoc Committee efforts.

Reports by Management and General Counsel
SDCP Management and General Counsel may briefly provide information to the Board and the public.

The Board may engage in discussion if the specific subject matter of the report is identified below, but the Board may not take any action other than to place the matter on a future agenda. Otherwise, there is to be no discussion or action taken unless authorized by law.

Director Comments
Board Members may briefly provide information to other members of the Board and the public, ask questions of staff, request an item to be placed on a future agenda, or report on conferences, events, or activities related to SDCP business. There is to be no discussion or action taken on comments made by Directors unless authorized by law.

Availability of Board Documents
Copies of the agenda and agenda packet are available at https://sdcommunitypower.org/resources/meeting-notes/. Late-arriving documents related to a Board meeting item which are distributed to a majority of the Members prior to or during the Board meeting are available for public review as required by law. Previously, public records were available for inspection at the City of San Diego Sustainability Department, located at 1200 Third Ave., Suite 1800, San Diego, CA 92101. However, due to the Governor’s Executive Orders N-25-20 and N-29-20 and the need for social distancing, in-person inspection is now suspended. Public records, including agenda-related documents, can instead be requested electronically at [email protected] or by mail to SDCP, 815 E Street, Suite 12716, San Diego, CA 92112. The documents may also be posted at the above website.

MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 1 SAN DIEGO COMMUNITY POWER (SDCP)

BOARD OF DIRECTORS
San Diego City Administration Building, 12th Floor
202 “C” Street
San Diego, CA 92101

MINUTES
September 23, 2021
This meeting was conducted utilizing teleconferencing and electronic means consistent with State of California Executive Order N-29-20 dated March 17, 2020, regarding the COVID-19 pandemic.

The Board minutes are prepared and ordered to correspond to the Board Agenda. Agenda Items can be taken out of order during the meeting.

The Agenda Items were considered in the order presented.

WELCOME
General Counsel Baron announced there were no reportable actions from Closed Session.

Interim Board Clerk Wiegelman read aloud the first 400 words of the emailed public comments submitted by 3:00 p.m. the day of the Board meeting for Item 2 under Regular Agenda. The comments were considered under Regular Agenda Item 2.

Michelle Morgan submitted a comment regarding the recruitment and hiring of a permanent Chief Executive Officer.

Karinna Gonzalez submitted a comment regarding the recruitment and hiring of a permanent Chief Executive Officer.

Shelah Ott submitted a comment regarding the recruitment and hiring of a permanent Chief Executive Officer.

Matthew Vasilakis, Climate Action Campaign, spoke regarding the timeline for hiring a permanent Chief Executive Officer.

Joyce Lane spoke regarding the extension of the Interim Chief Executive Officer Employment Contract and the hiring of a permanent Chief Executive Officer.

Tara Hammond, Community Advisory Committee (“CAC”) Vice Chair, spoke regarding the recruitment and hiring of a permanent Chief Executive Officer.

Chair Mosca adjourned the Closed Session at 5:16 p.m.

CALL TO ORDER
MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 2 Chair Mosca (Encinitas) called the SDCP Board of Directors meeting to order at 5:16 p.m.

PLEDGE OF ALLEGIANCE
Chair Mosca (Encinitas) led the Pledge of Allegiance.

ROLL CALL
PRESENT: Chair Mosca (Encinitas), Vice Chair Padilla (Chula Vista), Director Baber (La Mesa), Director Dedina (Imperial Beach), and Director Montgomery Steppe (San Diego)
ABSENT: None
Also Present: Interim Chief Executive Officer (“CEO”) Carnahan, Chief Operating Officer (“COO”) Hooven, General Counsel Baron, Interim Board Clerk Wiegelman

ITEMS TO BE ADDED, WITHDRAWN, OR REORDERED ON THE AGENDA There were no additions or deletions to the agenda.

PUBLIC COMMENTS
There were no comments.

CONSENT CALENDAR
(Item 1)

1. Treasurer’s Report – Presentation of Financial Results for 2021 Fiscal Year End Period ended 6/30/21 and Presentation of Financial Results for Fiscal Year 2022 Period ended 7/31/21
Received and filed.

ACTION: Motioned by Director Montgomery Steppe (San Diego) and seconded by Director Dedina (Imperial Beach) to approve Consent Calendar Item 1. The motion carried by the following vote:

Vote: 5-0
Yes: Chair Mosca (Encinitas), Director Padilla (Chula Vista), Director Baber (La Mesa), Director Dedina (Imperial Beach), and Director Montgomery Steppe (San Diego) No: None
Abstained: None

Absent: None

REPORTS BY MANAGEMENT AND GENERAL COUNSEL
MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 3 General Counsel Baron reported on Assembly Bill 361 (AB 361) which amended the Brown Act to allow local legislative bodies to continue using teleconferencing and virtual meeting technology after the September 30, 2021, expiration of the current Brown Act exemptions as long as there was a “proclaimed state of emergency” by the Governor.

REGULAR AGENDA

2. First Amendment to Interim Chief Executive Officer Employment Agreement General Counsel Baron gave an overview of Bill Carnahan’s professional experience and provided background on the hiring of Bill Carnahan as Interim CEO. General Counsel Baron summarized the first amendment to the Interim CEO Employment Agreement.

The First Amendment to the Interim CEO Employment Agreement would:
• Extend Bill Carnahan’s term of employment for up to six (6 months). Mr. Carnahan’s employment would remain “at-will” and at the pleasure of the Board of Directors. • Add a housing per diem of $200 per day for each night Mr. Carnahan were to stay in San Diego County in relation to performing his duties as Interim CEO, with a limit of ten (10) per diems per calendar month.
• All other aspects of the Interim CEO Employment Agreement, including salary and other benefits, would remain the same.
o Base annual salary of two hundred ninety five thousand dollars ($295,000); o A gross monthly vehicle allowance of five hundred dollars ($500) per month; o A SDCP owned cell phone and accompanying SDCP paid plan or a one hundred dollars ($100) monthly taxable technology allowance; and o In lieu of employee benefits, Mr. Carnahan would receive compensation equivalent to benefits he might otherwise be entitled to as a permanent SDCP employee in an amount equal to fifteen percent (15%) of his base annual salary.

Joyce Lane spoke informing the Board that her comment at the beginning of the meeting was intended for this item.

Board questions and comments ensued.

City Clerk Wiegelman stated the public comments read and heard at the beginning of the meeting under Closed Session were intended for Item 2 of the Regular meeting and were taken into consideration during Item 2.

Board questions and comments continued.

ACTION: Motioned by Vice Chair Padilla (Chula Vista) and seconded by Chair Mosca (Encinitas) to approve the First Amendment to the Interim Chief Executive Officer Employment Agreement with Bill Carnahan. The motion carried by the following vote:

Vote: 5-0
MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 4 Yes: Chair Mosca (Encinitas), Director Padilla (Chula Vista), Director Baber (La Mesa), Director Dedina (Imperial Beach), and Director Montgomery Steppe (San Diego) No: None
Abstained: None

Absent: None

3. Consider and Discuss Recruitment Process for Permanent Chief Executive Officer General Counsel Baron reviewed the terms of SDCP’s Joint Powers Agreement as it relates to the appointment of a CEO. General Counsel Baron provided an overview of the previous CEO recruitment process and stated under SDCP’s procurement policy, the contract for a recruitment firm would not need to be brought back to the Board for approval unless directed to do so by the Board. General Counsel Baron requested Board direction regarding the hiring of an executive recruiter and the establishment of a temporary ad hoc advisory committee related to the executive recruitment.

Board questions and comments ensued.

Matthew Vasilakis, Climate Action Campaign, spoke regarding the CEO recruitment process and including the CAC and community stakeholders in the process.

Eddie Price, CAC Chair, spoke regarding the timeline for the recruitment and hiring of a permanent CEO.

Board questions and comments continued.

ACTION: Motioned by Director Baber (La Mesa) and seconded by Chair Mosca (Encinitas) to: (1) to direct staff to hire an executive recruiter and (2) establish an ad hoc subcommittee comprising of Director Baber and Vice Chair Padilla for the purpose of working with the executive recruiter and participating in the recruitment process. The motion carried by the following vote:

Vote: 5-0
Yes: Chair Mosca (Encinitas), Vice Chair Padilla (Chula Vista), Director Baber (La Mesa), Director Dedina (Imperial Beach), and Director Montgomery Steppe (San Diego) No: None
Abstained: None

Absent: None

4. Update on Regulatory and Legislative Affairs
Regulatory and Legislative Affairs Director Fernandez provided an update on the end of the 2021 California legislative session, the San Diego Gas and Electric (“SDG&E”) sales forecast (Application 21-08-010), the Resource Adequacy (“RA”) citation appeal, and the Net Energy Metering (“NEM”) 3.0 proceeding.

Following Board questions and comments, no action was taken

5. Net Energy Metering Letter to the California Public Utilities Commission and the Governor’s Office as Recommended by the Community Advisory Committee MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 5 Regulatory and Legislative Affairs Director Fernandez informed the Board that the next step in the NEM 3.0 proceeding was for a Proposed Decision (“PD”) to be issued by the Administrative Law Judge (“ALJ”) in the proceeding and the California Public Utilities Commission (“CPUC”) staff would consider information that was submitted on the record in the proceeding to inform the PD.

Regulatory and Legislative Affairs Director Fernandez stated the CAC had discussed the issue during several past meetings and had voted unanimously to recommend to the Board that a letter be sent to the CPUC and Governor’s Office on behalf of SDCP calling for the proceeding to adopt a strong NEM 3.0 structure that maintains a sustainable growth of the rooftop solar industry.

Board questions and comments ensued.

The following members of the public spoke in support of sending a letter supporting a strong NEM

3.0 structure that maintains a sustainable growth of the rooftop solar industry to the CPUC and Governor’s Office:

Eddie Price, CAC Chair
Joyce Lane
Matthew Vasilakis, Climate Action Campaign
Karinna Gonzalez
Trent Laura
Tara Hammond, CAC Vice Chair
The following member of the public spoke in opposition to sending a letter supporting a strong NEM 3.0 structure that maintains a sustainable growth of the rooftop solar industry to the CPUC and Governor’s Office:

Tony Cruz, SDG&E
Interim Board Clerk Wiegelman read aloud the first 400 words of the emailed public comments submitted by 3:00 p.m. the day of the Board meeting.

The following members of the public submitted a comment in support of sending a letter supporting a strong NEM 3.0 structure that maintains a sustainable growth of the rooftop solar industry to the CPUC and Governor’s Office:

Elexa Bribiesca
Gabe von Wellsheim, Aloha Solar Power
Michelle Morgan
David Rosenfeld, Solar Rights Alliance
Evelyn Blanco
Marie Chen
Shelah Ott
Board questions and comments continued.

ACTION: Motioned by Director Montgomery Steppe (San Diego) and seconded by Director Baber (La Mesa) to approve the CAC’s recommendation to send a letter supporting NEM to the CPUC and Governor’s Office with staff edits and direct staff to engage with other Community Choice MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 6 Aggregations to sign onto the letter but to not delay sending the letter. The motion carried by the following vote:

Vote: 5-0
Yes: Chair Mosca (Encinitas), Vice Chair jPadilla (Chula Vista), Director Baber (La Mesa), Director Dedina (Imperial Beach), and Director Montgomery Steppe (San Diego) No: None
Abstained: None

Absent: None

6. Resolution to Approve County of San Diego Membership in SDCP COO Hooven provided an overview of the timeline, process, and economic assessment of the impacts of adding the County of San Diego (“County”) as a member of SDCP. COO Hooven explained the impact the new membership would have on voting.

Board questions and comments ensued.

Matthew Vasilakis, Climate Action Campaign, spoke in support of adopting the Resolution to approve the County’s membership in SDCP.

Board questions and comments continued.

ACTION: Motioned by Director Baber (La Mesa) and seconded by Director Dedina (Imperial Beach) to adopt Resolution No. 2021-4, a Resolution of the Board of Directors approving the addition of the County of San Diego as a member of SDCP. The motion carried by the following vote:

Absent: None

7. New Members Discussion: National City and Oceanside
COO Hooven stated Oceanside was no longer considering membership in SDCP.

John Dalessi, Pacific Energy Advisors (“PEA”), provided an overview of the customer base and energy consumption of National City and the economic assessment of the impacts of adding National City as a member of SDCP.

COO Hooven reviewed the next steps in the process of adding National City as a member of SDCP.

Following Board questions and comments, no action was taken.

MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 7 8. Employee Handbook Update
COO Hooven provided an overview of the Employee Handbook’s COVID-19 vaccination policy.

Following Board questions and comments, no action was taken.

9. Energy Programs Discussion and Overview
COO Hooven and Program Manager Lomeli provided an overview of the program prioritization for Fiscal Year 2021-2022.

Program Manager Lomeli reviewed the various programs in the following categories:
• Phase 3 Programs – programs that were necessary to implement in order to serve customers transitioning into SDCP service or programs that were previously adopted by the Board.
o Net Energy Metering
o Renewable Energy Self-Generation Bill Credit Transfer o Feed-in Tariff
• Low-Income Focused Programs
o Disadvantaged Communities Green Tariff
o Community Solar Green Tariff
• Partnership with Member Agencies Programs
o Local Government Commission
o Member Agency Funding Pilot
• Looking Ahead
o Community Power Plan
• On the Horizon
o Elect-To-Administer
o Regional Energy Network
Following Board questions and comments, no action was taken.

10. Back Office Metrics and Dashboard Monthly Update
Data Analytics and Account Services Director Utouh gave an update on the Phase 3 enrollment planning, the tracking of the opt out/up actions, and the contact center metrics.

Following Board questions and comments, no action was taken.

11. Power Resources Monthly Update
Power Resources Director Vosburg provided an update on the energy market, renewable energy, resource adequacy, and risk management.

Cristina Marquez, IBEW Local 569, spoke on amending the inclusive and sustainable workforce policy and developing bid evaluation scoring criteria.

Following Board questions and comments, no action was taken.

MINUTES – BOARD OF DIRECTORS – SAN DIEGO COMMUNITY POWER 8 DIRECTOR COMMENTS
There were no comments.

REPORTS BY MANAGEMENT AND GENERAL COUNSEL
There were no reports.

ADJOURNMENT
Chair Mosca (Encinitas) adjourned the meeting at 7:34 p.m.

Megan Wiegelman, CMC
Interim Board Clerk

SAN DIEGO COMMUNITY POWER
Staff Report – Item 2
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Eric W. Washington, Chief Financial Officer
Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Treasurer’s Report –Presentation of Financial Results for Fiscal Year 2022 Period ended 11/30/21
Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive and File Report

BACKGROUND
San Diego Community Power (SDCP) maintains its accounting records on a full accrual basis in accordance with Generally Accepted Accounting Principles (GAAP) as applicable to governmental enterprise funds.

SDCP has prepared year-to-date financial statements for the period ended November 30, 2022, along with budgetary comparisons.

ANALYSIS AND DISCUSSION
Financial results for the period ended 11/31/21: $171.69 million in net operating revenues were reported compared to $154.71 million budgeted for the period. $145.62 million in total expenses were reported (including $142.77 million in energy cost) compared to $137.96 million budgeted for the period (including $133.93 budgeted for energy costs).

After expenses, SDCP’s change in net position of $26.07 million was reported. The following is a summary to actual results compared to the Fiscal Year 2022 Budget. • Net operating revenues finished $16.98 million (or 11%) ahead of budget • Operating expenses came in over budget by 6%
Budget Comparison
YTD FY22 as of
11/30/21 (5 mos)
FY22 YTD
Budget
Budget
Variance ($) Budget (%)
Net Operating Revenues $ 171,688,410 $ 154,711,116 $ 16,977,294 111 Total Expenses $ 145,620,316 $ 137,961,797 $ 7,658,519 106 Change in Net Position $ 26,068,094 $ 16,749,319 $ 9,318,775 Financial results for period remained in line with projections presented in the year-to-date proforma. SDCP’s change in net position was 4.42% over the projection. The following is a summary to actual results compared to the fiscal year-to-date proforma.

COMMITTEE REVIEW
The report was not reviewed by the Financial Risk Management Committee (FRMC)

FISCAL IMPACT
N/A

ATTACHMENTS
Attachment A: 2022 Year-to-Date Period Ended 11/30/21 Financial Statements Proforma Comparison
YTD FY22 as of
11/30/21 (5 mos)
FY22 YTD
ProForma
ProForma
Variance ($) Proforma (%)
Net Operating Revenues $ 171,688,410 $ 173,280,085 $ (1,591,675) -0.92% Total Expenses $ 145,620,316 $ 148,315,466 $ (2,695,150) -1.82% Change in Net Position $ 26,068,094 $ 24,964,619 $ 1,103,475 4.42% $-
$20,000,000
$40,000,000
$60,000,000
$80,000,000
$100,000,000
$120,000,000
$140,000,000
$160,000,000
$180,000,000
$200,000,000
Net Operating Revenues Total Expenses Change in Net Position YTD FY22 Results v. Budget
YTD FY22 as of 11/30/21 (5 mos) FY22 YTD Budget
1 ACCOUNTANTS’ COMPILATION REPORT
Management
San Diego Community Power
Management is responsible for the accompanying financial statements of San Diego Community Power (a California Joint Powers Authority) which comprise the statement of net position as of November 30, 2021, and the related statement of revenues, expenses, and changes in net position, and the statement of cash flows for the period then ended in accordance with accounting principles generally accepted in the United States of America. We have performed a compilation engagement in accordance with Statements on Standards for Accounting and Review Services promulgated by the Accounting and Review Services Committee of the AICPA. We did not audit or review the accompanying statements nor were we required to perform any procedures to verify the accuracy or completeness of the information provided by management. Accordingly, we do not express an opinion, conclusion, nor provide any assurance on these financial statements.

Management has elected to omit substantially all of the note disclosures required by accounting principles generally accepted in the United States of America in these interim financial statements. If the omitted disclosures were included in these financial statements, they might influence the user’s conclusions about the Authority’s financial position, results of operations, and cash flows. Accordingly, these financial statements are not designed for those who are not informed about such matters.

We are not independent with respect to the Authority because we performed certain accounting services that impaired our independence.

Maher Accountancy
San Rafael, CA
January 7, 2022
1101 Fifth Avenue, Suite 200 San Rafael, CA 94901 415 459 1249 mahercpa.com Current assets
Cash and cash equivalents 28,217,689 $
Accounts receivable, net 29,618,424
Accrued revenue 11,872,241
Prepaid expenses 43,585
Energy settlements and other receivables 2,648,879
Deposits 5,843,708
Total current assets 78,244,526
Noncurrent assets
Restricted cash 9,000,000
Deposits 3,050,000
Total noncurrent assets 12,050,000
Total assets 90,294,526
Current liabilities
Accrued cost of energy 48,616,860
Accounts payable 374,821
Other accrued liabilities 116,773
Due to other governments 181,537
Security deposits 570,000
Interest payable 57,255
Bank note payable 22,840,082
Total current liabilities 72,757,328
Noncurrent liabilities
Other noncurrent liabilities 517,741
Loans payable 5,000,000
Total noncurrent liabilities 5,517,741
Total liabilities 78,275,069
Unrestricted 12,019,457
Total net position 12,019,457 $

NET POSITION

SAN DIEGO COMMUNITY POWER

STATEMENT OF NET POSITION
As of November 30, 2021
ASSETS

LIABILITIES
See accountants' compilation report. 2

OPERATING REVENUES
Electricity sales, net 171,688,410 $

OPERATING EXPENSES
Cost of energy 142,765,773
Contract services 1,041,318
Staff compensation 1,198,938
General and administration 367,809
Total operating expenses 145,373,838
Operating income (loss) 26,314,572

NONOPERATING EXPENSES
Interest and financing expense 246,478
Nonoperating expenses 246,478
CHANGE IN NET POSITION 26,068,094
Net position at beginning of period (14,048,637)
Net position at end of period 12,019,457 $

SAN DIEGO COMMUNITY POWER

STATEMENT OF REVENUES, EXPENSES

AND CHANGES IN NET POSITION
Five Months Ended November 30, 2021
See accountants' compilation report. 3

CASH FLOWS FROM OPERATING ACTIVITIES
Receipts from customers 143,997,727 $
Other operating receipts 5,107,487
Payments to suppliers for electricity (114,006,728)
Payments for goods and services (1,441,075)
Payments to employees for services (1,170,597)
Payments for deposits and collateral (5,443,708)
Tax and surcharge payments to other governments (293,296) Net cash provided (used) by operating activities 26,749,810

CASH FLOWS FROM NON-CAPITAL FINANCING ACTIVITIES
Interest and related expense payments (252,687)
Net cash provided (used) by non-capital
financing activities (252,687)
Net change in cash and cash equivalents 26,497,123
Cash and cash equivalents at beginning of period 10,720,566 Cash and cash equivalents at end of period 37,217,689 $ Reconciliation to the Statement of Net Position
Cash and cash equivalents (unrestricted) 28,217,689
Restricted cash 9,000,000
Cash and cash equivalents 37,217,689 $

SAN DIEGO COMMUNITY POWER

STATEMENT OF CASH FLOWS
Five Months Ended November 30, 2021
See accountants' compilation report. 4
Operating income 26,314,572 $
Adjustments to reconcile operating income (loss) to net cash provided (used) by operating activities
Revenue adjusted for allowance for uncollectible accounts 1,734,226 (Increase) decrease in:

Accounts receivable (30,236,529)
Accrued revenue 348,068
Energy settlements and other receivables 1,394,393
Prepaid expenses (43,585)
Deposits (4,993,708)
Increase (decrease) in:

Accrued cost of electricity 32,472,139
Accounts payable 12,539
Other accrued liabilities 27,439
User taxes due to other governments 170,256
Supplier security deposits (450,000)
Net cash provided (used) by operating activities 26,749,810 $

SAN DIEGO COMMUNITY POWER
STATEMENT OF CASH FLOWS (continued)
Five Months Ended November 30, 2021

RECONCILIATION OF OPERATING INCOME TO NET

CASH PROVIDED (USED) BY OPERATING ACTIVITIES
See accountants' compilation report. 5
1 ACCOUNTANTS’ COMPILATION REPORT
Board of Directors
San Diego Community Power
Management is responsible for the accompanying special purpose statement of San Diego Community Power (SDCP), a California Joint Powers Authority, which comprise the budgetary comparison schedule for the period ended November 30, 2021, and for determining that the budgetary basis of accounting is an acceptable financial reporting framework. We have performed a compilation engagement in accordance with Statements on Standards for Accounting and Review Services promulgated by the Accounting and Review Services Committee of the AICPA. We did not audit or review the accompanying statement nor were we required to perform any procedures to verify the accuracy or completeness of the information provided by management. Accordingly, we do not express an opinion, a conclusion, nor provide any assurance on this special purpose budgetary comparison statement.

The special purpose statement is prepared in accordance with the budgetary basis of accounting, which is a basis of accounting other than accounting principles generally accepted in the United States of America. This report is intended for the information of the Board of Directors of SDCP.

Management has elected to omit substantially all of the note disclosures required by accounting principles generally accepted in the United States of America in these interim financial statements.

SDCP’s annual audited financial statements will include the note disclosures omitted from these interim statements. If the omitted disclosures were included in these financial statements, they might influence the user’s conclusions about the Authority’s financial position, results of operations, and cash flows.

Accordingly, these financial statements are not designed for those who are not informed about such matters.

We are not independent with respect to SDCP because we performed certain accounting services that impaired our independence.

Maher Accountancy
San Rafael, CA
January 7, 2022
1101 Fifth Avenue, Suite 200 San Rafael, CA 94901 415 459 1249 mahercpa.com 2021/22 YTD
Budget
2021/22 YTD
Actual
2021/22 YTD
Budget
Variance
(Under) Over
2021/22
YTD
Actual/
Budget %
2021/22 Annual
Budget
2021/22 Budget
Remaining
REVENUES AND OTHER SOURCES Gross Ratepayer Revenues 156,273,854 173,422,636 $ 17,148,782 111% 318,321,000 $ 144,898,364 $ Less 1% Uncollectible Customer Accounts (1,562,739) (1,734,226) (171,487) 0% (3,183,000) (1,448,774) Total Revenues and Other Sources 154,711,116 171,688,410 16,977,294 315,138,000 143,449,590 OPERATING EXPENSES Cost of Energy 133,926,707 142,765,773 8,839,066 107% 284,304,000 141,538,227 Personnel Costs 1,509,762 1,198,938 (310,824) 79% 4,885,000 3,686,062 Professional Services and Consultants 1,334,145 831,686 (502,459) 62% 4,981,000 4,149,314 Marketing and Outreach 457,705 344,539 (113,166) 75% 1,417,000 1,072,461 General and Administrative 325,500 232,902 (92,598) 72% 845,000 612,098 Total Operating Expenses 137,553,818 145,373,838 7,820,020 296,432,000 151,058,162 Operating Income (Loss) 17,157,297 26,314,572 9,157,275 18,706,000 (7,608,572) NON-OPERATING REVENUES (EXPENSES) Debt Service and Bank Fees (407,979) (246,478) 161,501 0% (978,000) (731,522) Total Non-Operating Revenues (Expenses) (407,979) (246,478) 161,501 (978,000) (731,522) CHANGE IN NET POSITION $ 26,068,094 16,749,318 $ 9,318,776 $ 17,728,000 $ (8,340,094) $

SAN DIEGO COMMUNITY POWER

BUDGETARY COMPARISON SCHEDULE
Five Months Ended November 30, 2021

SAN DIEGO COMMUNITY POWER
Staff Report – Item 3
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Eric W. Washington, Chief Financial Officer
Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Receive and File 6/30/21 Fiscal Year End Audited Financial Statement Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive and file report.

BACKGROUND
San Diego Community Power’s JPA requires an annual financial statement audit performed by an independent auditor. Pisenti & Brinker was chosen to perform the audit.

This firm has extensive experience auditing CCA’s throughout California, as well as other local government entities.

ANALYSIS AND DISCUSSION
Pisenti & Brinker prepared a presentation describing the audit process and results.

COMMITTEE REVIEW
Pisenti & Brinker conducted the audit process and result of the 6/30/21 fiscal year end audit report to the Finance and Risk Management Committee meeting held on November 16, 2021.

FISCAL IMPACT
Not applicable

ATTACHMENTS
Attachment A: Audited Financial Statements for Fiscal Year Ended June 30, 2021

SAN DIEGO COMMUNITY POWER

FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021
AND PERIOD ENDED JUNE 30, 2020

WITH REPORT OF

INDEPENDENT AUDITORS

TABLE OF CONTENTS
Independent Auditor’s Report ………………………………………………….......... 1 Management’s Discussion and Analysis ……………………………………………... 3 Basic Financial Statements:

Statements of Net Position …………………………………………………… 9
Statements of Revenues, Expenses and Changes in Net Position …................ 10 Statements of Cash Flows ……………………………………………………. 11
Notes to the Basic Financial Statements ……………………………………… 13 A.

SANTA ROSA    PETALUMA
RSM US Alliance member firms are separate and independent businesses and legal entities that are responsible for their own acts and omissions, and each are separate and independent from RSM US LLP. RSM US LLP is the U.S. member firm of RSM International, a global network of independent audit, tax, and consulting firms. Members of RSM US Alliance have access to RSM International resources through RSM US LLP but are not member firms of RSM International. 3562 Round Barn Circle, Suite 200
Santa Rosa, CA 95403
(707) 542‐3343    Office
(707) 527‐5608    Fax
pbllp.com
Independent Auditor’s Report
To the Board of Directors
San Diego Community Power
San Diego, California
Report on the Financial Statements
We have audited the accompanying financial statements of San Diego Community Power (SDCP), as of and for the year ended June 30, 2021 and the period from October 1, 2019 (inception date) through June 30, 2020, and the related notes to the financial statements, which collectively comprise SDCP’s financial statements as listed in the table of contents.

Management’s Responsibility for the Financial Statements Management is responsible for the preparation and fair presentation of these financial statements in accordance with accounting principles generally accepted in the United States of America; this includes the design, implementation, and maintenance of internal control relevant to the preparation and fair presentation of financial statements that are free from material misstatement, whether due to fraud or error.

Auditor’s Responsibility
Our responsibility is to express an opinion on these financial statements based on our audits. We conducted our audits in accordance with auditing standards generally accepted in the United States of America. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the financial statements are free from material misstatement.

An audit involves performing procedures to obtain audit evidence about the amounts and disclosures in the financial statements. The procedures selected depend on the auditor’s judgment, including the assessment of the risks of material misstatement of the financial statements, whether due to fraud or error.

In making those risk assessments, the auditor considers internal control relevant to the entity’s preparation and fair presentation of the financial statements in order to design audit procedures that are appropriate in the circumstances, but not for the purpose of expressing an opinion on the effectiveness of the entity’s internal control. Accordingly, we express no such opinion. An audit also includes evaluating the appropriateness of accounting policies used and the reasonableness of significant accounting estimates made by management, as well as evaluating the overall presentation of the financial statements.

We believe that the audit evidence we have obtained is sufficient and appropriate to provide a basis for our audit opinion.

Opinion
In our opinion, the financial statements referred to above present fairly, in all material respects, the financial position of San Diego Community Power as of June 30, 2021 and 2020 and the changes in financial position and cash flows for the periods then ended in accordance with accounting principles generally accepted in the United States of America.

Independent Auditor’s Report (continued)
Other Matters
Accounting principles generally accepted in the United States of America require that the management’s discussion and analysis as listed in the table of contents be presented to supplement the basic financial statements. Such information, although not a part of the basic financial statements, is required by the Governmental Accounting Standards Board, who considers it to be an essential part of financial reporting for placing the basic financial statements in an appropriate operational, economic, or historical context.

We have applied certain limited procedures to the required supplementary information in accordance with auditing standards generally accepted in the United States of America, which consisted of inquiries of management about the methods of preparing the information and comparing the information for consistency with management’s responses to our inquiries, the basic financial statements, and other knowledge we obtained during our audit of the basic financial statements. We do not express an opinion or provide any assurance on the information because the limited procedures do not provide us with sufficient evidence to express an opinion or provide any assurance.

Santa Rosa, California
December 16, 2021

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 3 The Management’s Discussion and Analysis provides an overview of San Diego Community Power’s (SDCP) financial activities as of and for the year ended June 30, 2021, and from inception (October 1, 2019) through June 30, 2020. The information presented here should be considered in conjunction with the audited financial statements.

BACKGROUND
The formation of SDCP was made possible in 2002 by the passage of California Assembly Bill 117, enabling communities to purchase power on behalf of their residents and businesses and creating competition in power generation.

SDCP was created as a California Joint Powers Authority (JPA) effective October 1, 2019, and was established to provide electric power at competitive costs as well as to provide other benefits to its members (County of San Diego and the cities of Chula Vista, Encinitas, Imperial Beach, La Mesa and San Diego), including reducing greenhouse gas emissions related to the use of power, procuring energy with a priority on the use and development of local renewable resources, stimulating local job creation through various programs and development, promote personal and community ownership of renewable resources, as well as promoting long-term electric rate stability and energy reliability for residents and businesses. Governed by a board of directors (Board) consisting of elected representatives from each jurisdiction, SDCP has the rights and powers to set rates for the services it furnishes, incur indebtedness, and issue bonds or other obligations. SDCP will be responsible for the acquisition of electric power for its service area.

SDCP began providing electricity to municipal customers in March 2021 and commercial customers in June 2021.

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 4 Financial Reporting
SDCP presents its financial statements as an enterprise fund under the economic resources measurement focus and accrual basis of accounting, in accordance with Generally Accepted Accounting Principles (GAAP) for proprietary funds, as prescribed by the Governmental Accounting Standards Board (GASB).

Contents of this report
This report is divided into the following sections:
 Management discussion and analysis, which provides an overview of the financial operations.
 The basic financial statements:
o The Statements of Net Position include all of SDCP’s assets, liabilities, and net position and provide information about the nature and amount of resources and obligations at a specific point in time.
o The Statements of Revenues, Expenses, and Changes in Net Position report all of SDCP’s revenue and expenses for the year and period shown. o The Statements of Cash Flows report the cash provided and used by operating activities, as well as other sources and uses, such as debt financing. o Notes to the Basic Financial Statements provide additional details and information related to the basic financial statements.

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 5 FINANCIAL HIGHLIGHTS
The following table is a summary of SDCP’s assets, liabilities, and net position and a discussion of significant changes for the year ended June 30 2021 and the period from inception to June 30, 2020:
2021 2020
Current assets 20,750,268 $ 363,982 $
Noncurrent assets 11,250,000 5,600,000
Total assets 32,000,268 5,963,982
Current liabilities 40,531,164 566,834
Noncurrent liabilities 5,517,741 6,467,258
Total liabilities 46,048,905 7,034,092
Net position
Unrestricted (deficit) (14,048,637) (1,070,110)
Total net position (14,048,637) $ (1,070,110) $
Current assets
Current assets were approximately $20,750,000 at the end of 2020-21 and were primarily comprised of cash of $1,721,000, accounts receivable from retail customers of $1,116,000, and accrued revenue of $12,220,000, each of which mark an increase from 2019-20. SDCP did not start providing electricity to customers until March 2021, so at the end of fiscal year 2019-20 current assets mostly consisted of cash. Accrued revenue differs from accounts receivable in that it is the result of electricity use by SDCP customers before invoicing to those customers has occurred.

Noncurrent assets
Noncurrent assets are comprised of restricted cash and deposits in SDCP’s name held by other parties, primarily as collateral on debt. As SDCP began securing electricity to sell to customers, various energy contracts required deposits which accounts for the large increase in noncurrent assets.

Current liabilities
The largest component of current liabilities, besides a bank note payable, is the cost of electricity delivered to customers that is not yet due to paid by SDCP. Other components include trade accounts payable, security deposits due to energy suppliers, and various other accrued liabilities.

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 6 Current liabilities (continued)
In 2019-20, the bank note payable was considered a noncurrent liability. In 2020-21, the bank note payable is considered a current liability as the maturity falls within twelve months of the year end. Increased borrowings as described in the Notes to the Financial Statements along with the presence of accrued cost of energy for the first time in 2020-21 accounts for the large increase in current liabilities.

Noncurrent liabilities
During 2019-20, SDCP borrowed $990,000 from River City Bank and $5,000,000 from private parties. The $5,000,000 private debt was incurred to provide for the cash collateral requirement of the River City Bank revolving line of credit. During 2020-21 SDCP borrowed an additional $21,850,000 from River City Bank. The River City Bank debt is considered a current liability in 2020-21.

Other noncurrent liabilities include $518,000 for start-up related costs owed primarily to the City of San Diego.

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 7 The following table is a summary of SDCP’s results of operations and a discussion of significant changes for the year ended June 30 2021 and the period from inception to June 30, 2020:
2021 2020
Operating revenues 14,809,010 $ - $
Operating expenses 27,551,819 1,006,369
Nonoperating expenses 235,718 63,741
Total expenses 27,787,537 1,070,110
Change in net position (12,978,527) $ (1,070,110) $
Operating revenues
SDCP began selling electricity to retail customers in March 2021, which accounts for the change compared to 2019-20. As of June 30, 2021, SDCP had approximately 72,000 municipal and commercial customer accounts.

Operating expenses
Expenses incurred during 2019-20 were the result of the start-up and implementation of SDCP.

No expenses during the period were related to energy purchases. The increase in operating expenses from 2019-20 to 2020-21 is largely the result of energy purchases needed to provide for municipal and commercial customer use. SDCP procures energy from a variety of sources and focuses on purchasing at competitive costs and maintaining a balanced renewable power portfolio.

Expenses for staff compensation, contract services, and other general and administrative expenses increased in 2020-21 as the organization grew to operational strength.

Nonoperating expenses
Interest expense on borrowings during the year ended June 30 2021 and the period from inception to June 30, 2020 are included as nonoperating expenses. Interest expense increased as a result of increased borrowings.

SAN DIEGO COMMUNITY POWER
MANAGEMENT’S DISCUSSION AND ANALYSIS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 8 ECONOMIC OUTLOOK
SDCP began to provide electricity to its municipal customers in March 2021. Delivery of electricity to its commercial and industrial customers began in June 2021. Customer groups will continue to be added during multiple phases throughout fiscal year 2022, including a major enrollment of residential customers. In August 2021, the County of San Diego voted to join SDCP.

Other cities in the region continue to consider joining SDCP. Prior to adding new cities, SDCP performs a thorough cost benefit analysis to determine whether the addition would be mutually beneficial.

In the normal course of business, SDCP enters into various agreements, including renewable energy agreements and other power purchase agreements to purchase power and electric capacity.

SDCP enters into power purchase agreements in order to comply with state law and voluntary targets for renewable and greenhouse gas (GHG) free products.

REQUEST FOR INFORMATION
This financial report is designed to provide SDCP’s customers and creditors with an overview of the SDCP’s finances and to demonstrate SDCP’s accountability for the funds under its stewardship.

Please address any questions about this report or requests for additional financial information to 815 E Street, Unit 12716, San Diego, CA 92112.

Respectfully submitted,
Bill Carnahan, CEO

BASIC FINANCIAL STATEMENTS

SAN DIEGO COMMUNITY POWER

STATEMENTS OF NET POSITION
JUNE 30, 2021 AND 2020
9 The accompanying notes are an integral part of these financial statements. 2021 2020
Current assets
Cash and cash equivalents 1,720,566 $ 338,982 $
Accounts receivable, net 1,116,121 -
Accrued revenue 12,220,309 -
Energy settlements receivable 4,043,272 -
Prepaid expenses - 25,000
Deposits 1,650,000 -
Total current assets 20,750,268 363,982
Noncurrent assets
Restricted cash 9,000,000 5,500,000
Deposits 2,250,000 100,000
Total noncurrent assets 11,250,000 5,600,000
Total assets 32,000,268 5,963,982
Current liabilities
Accrued cost of energy 16,144,721 -
Accounts payable 362,282 330,042
Other accrued liabilities 89,334 223,133
Due to other governments 11,281 -
Security deposits - energy suppliers 1,020,000 -
Interest payable 63,464 13,659
Bank note payable 22,840,082 -
Total current liabilities 40,531,164 566,834
Noncurrent liabilities
Other noncurrent liabilities 517,741 477,176
Bank note payable - 990,082
Loans payable 5,000,000 5,000,000
Total noncurrent liabilities 5,517,741 6,467,258
Total liabilities 46,048,905 7,034,092
Unrestricted (deficit) (14,048,637) (1,070,110)
Total net position (14,048,637) $ (1,070,110) $
ASSETS

LIABILITIES

NET POSITION

SAN DIEGO COMMUNITY POWER

STATEMENTS OF REVENUES, EXPENSES

AND CHANGES IN NET POSITION
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 10 The accompanying notes are an integral part of these financial statements. 2021
Inception to
June 30, 2020

OPERATING REVENUES
Electricity sales, net 14,809,010 $ - $

OPERATING EXPENSES
Cost of electricity 24,361,374 -
Contract services 2,069,504 529,193
Staff compensation 907,442 -
General and administration 213,499 477,176
Total operating expenses 27,551,819 1,006,369
Operating loss (12,742,809) (1,006,369)

NONOPERATING EXPENSES
Interest and financing expense 235,718 63,741
CHANGE IN NET POSITION (1,070,110) (12,978,527)
Net position at beginning of period (1,070,110) -
Net position at end of period (14,048,637) $ (1,070,110) $

SAN DIEGO COMMUNITY POWER

STATEMENTS OF CASH FLOWS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 11 The accompanying notes are an integral part of these financial statements. 2021
Inception to
June 30, 2020

CASH FLOWS FROM OPERATING ACTIVITIES
Receipts from customers 1,483,861 $ - $
Receipts of supplier collateral 1,581,000 -
Payments to suppliers for electricity (12,259,925) -
Payments for goods and services (2,407,429) (101,018)
Payments to employees for services (819,010) -
Payments for deposits and collateral (4,361,000) -
Net cash used by operating activities (16,782,503) (101,018)

CASH FLOWS FROM NON-CAPITAL

FINANCING ACTIVITIES
Proceeds from loans - 5,000,000
Proceeds from bank note 21,850,000 940,000
Interest and related expense payments (185,913) -
Net cash provided by non-capital
financing activities 21,664,087 5,940,000
Net change in cash and cash equivalents 4,881,584 5,838,982 Cash and cash equivalents at beginning of year 5,838,982 - Cash and cash equivalents at end of year 10,720,566 $ 5,838,982 $ Reconciliation to the Statements of Net Position
Cash and cash equivalents (unrestricted) 1,720,566 $ 338,982 $ Restricted cash 9,000,000 5,500,000
Cash and cash equivalents 10,720,566 $ 5,838,982 $
Noncash Non-Capital Financing Activities during the period ended June 30, 2020:

Expenses of $50,082 related to the acquisition of debt were financed from loan proceeds

SAN DIEGO COMMUNITY POWER

STATEMENTS OF CASH FLOWS (CONTINUED)
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 12 The accompanying notes are an integral part of these financial statements. 2021
Inception to
June 30, 2020
Operating loss (12,742,809) $ (1,006,369) $
Adjustments to reconcile operating loss to net
cash used by operating activities
Revenue adjusted for allowance for uncollectible accounts 149,586 - (Increase) decrease in:

Accounts receivable (1,265,707) -
Accrued revenue (12,220,309) -
Energy settlements and other receivables (4,043,272) -
Prepaid expenses 25,000 (25,000)
Deposits (3,800,000) (100,000)
Increase (decrease) in:

Accrued cost of electricity 16,144,721 -
Accounts payable 32,240 330,042
Other accrued liabilities (93,234) 700,309
Due to other governments 11,281 -
Security deposits - energy suppliers 1,020,000 -
Net cash used by operating activities (16,782,503) $ (101,018) $

RECONCILIATION OF OPERATING LOSS TO NET

CASH USED BY OPERATING ACTIVITIES

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 13 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

REPORTING ENTITY
San Diego Community Power (SDCP) is a California Joint Powers Authority created on October 1, 2019. As of the report date, parties to its Joint Powers Agreement consist of the following local governments:

County Cities
San Diego Chula Vista Imperial Beach
Encinitas San Diego
La Mesa
SDCP is separate from and derives no financial support from its members. SDCP is governed by a Board of Directors whose membership is composed of elected officials or other representatives of the member governments.

A core function of SDCP is to provide electric service that includes the use of renewable sources under the Community Choice Aggregation Program under California Public Utilities Code Section 366.2.

Electricity is acquired from commercial suppliers and delivered through existing physical infrastructure and equipment managed by San Diego Gas and Electric.

BASIS OF ACCOUNTING
SDCP’s financial statements are prepared in accordance with generally accepted accounting principles (GAAP). The Governmental Accounting Standards Board (GASB) is responsible for establishing GAAP for state and local governments through its pronouncements.

SDCP’s operations are accounted for as a governmental enterprise fund and are reported using the economic resources measurement focus and the accrual basis of accounting – similar to business enterprises. Accordingly, revenues are recognized when they are earned, and expenses are recognized at the time liabilities are incurred. Enterprise fund-type operating statements present increases (revenues) and decreases (expenses) in total net position. Reported net position is segregated into three categories, if applicable – investment in capital assets, restricted and unrestricted.

When both restricted and unrestricted resources are available for use, it is SDCP’s policy to use restricted resources first, then unrestricted resources as they are needed.

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 14 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued)

CASH AND CASH EQUIVALENTS
For the purpose of the Statements of Cash Flows, SDCP has defined cash and cash equivalents to include cash on hand, demand deposits, and short-term investments with an original maturity of three months or less. For the purpose of the Statements of Net Position, restricted cash balances are presented separately. Restricted cash reported on the Statements of Net Position includes collateral on a bank loan, as well as a required minimum balance to be maintained in one of its bank accounts.

ENERGY SETTLEMENTS RECEIVABLE
SDCP receives generation scheduling and other services from a registered California Independent System Operator (CAISO) scheduling coordinator. Energy settlements due from the scheduling coordinator were $4,043,272 and $0 as of June 30, 2021 and 2020, respectively.

DEPOSITS
Various energy contracts entered into by SDCP require SDCP to provide a supplier with a security deposit. These deposits are generally held for the term of the contract. Deposits are classified as current or noncurrent depending on the length of the time the deposits are expected to be held.

While these energy contract related deposits make up the majority of this item, other components may include deposits for regulatory and other operating purposes.

SECURITY DEPOSITS FROM ENERGY SUPPLIERS
Various energy contracts entered into by SDCP require the supplier to provide SDCP with a security deposit. These deposits are generally held for the term of the contract or until the completion of certain benchmarks. Deposits are classified as current or noncurrent depending on the length of time the deposits will be held.

OPERATING AND NONOPERATING REVENUE
Operating revenues include revenue derived from the provision of energy to retail and wholesale customers.

Interest income, when earned, will be considered “nonoperating revenue.”

ELECTRICAL POWER PURCHASED
During the normal course of business, SDCP purchases electrical power from numerous suppliers.

Electricity costs include the cost of energy and capacity arising from bilateral contracts with energy suppliers as well as generation credits, and load and other charges arising from SDCP’s participation in the California Independent System Operator’s centralized market. The cost of electricity and capacity is recognized as “Cost of Electricity” in the Statements of Revenues, Expenses and Changes in Net Position.

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 15 1. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (continued) ELECTRICAL POWER PURCHASED (continued)
To comply with the State of California’s Renewable Portfolio Standards (RPS) and self-imposed benchmarks, SDCP acquires RPS eligible renewable energy evidenced by Renewable Energy Certificates (Certificates) recognized by the Western Renewable Energy Generation Information System (WREGIS). SDCP obtains Certificates with the intent to retire them and does not sell or build surpluses of Certificates with a profit motive. SDCP recognizes an expense on a monthly basis that corresponds to the volume sold to its customers for its various renewable and carbon free products. This expense recognition increases accrued cost of energy reported on the Statements of Net Position. Payments made to suppliers reduce accrued cost of electricity.

SDCP purchases capacity commitments from qualifying generators to comply with the California Public Utilities Commission’s Resource Adequacy Program. The goals of the Resource Adequacy Program are to provide sufficient resources to the California Independent System Operator to ensure the safe and reliable operation of the grid in real-time and to provide appropriate incentives for the siting and construction of new resources needed for reliability in the future.

STAFFING COSTS
SDCP fully pays employees semi-monthly and fully pays its obligation for health benefits and contributions to its defined contribution retirement plan each month. SDCP is not obligated to provide post-employment healthcare or other fringe benefits and, accordingly, no related liability is recorded in these financial statements. SDCP provides compensated time off, and the related liability is recorded in these financial statements.

INCOME TAXES
SDCP is a joint powers authority under the provision of the California Government Code and is not subject to federal or state income or franchise taxes.

ESTIMATES
The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make estimates and assumptions that affect certain reported amounts and disclosures. Accordingly, actual results could differ from those estimates.

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 16 2. CASH AND CASH EQUIVALENTS
SDCP maintains its cash in accounts at River City Bank in Sacramento, California. SDCP’s deposits with River City Bank are subject to California Government Code Section 16521 which requires that River City Bank collateralize public funds in excess of the Federal Deposit Insurance Corporation limit of $250,000 by 110%. SDCP has no deposit or investment policy that addresses a specific type of risk that would impose restrictions beyond this code. Accordingly, the amount of risk is not disclosed. SDCP monitors its risk exposure to River City Bank on an ongoing basis.

3. ACCOUNTS RECEIVABLE
Accounts receivable were as follows:
2021 2020
Accounts receivable from customers 1,265,707 $ - $
Allowance for uncollectible accounts (149,586) -
Net accounts receivable 1,116,121 $ - $
The majority of account collections occur within the first few months following customer invoicing. SDCP estimates that a portion of the billed accounts will not be collected. SDCP continues collection efforts on accounts in excess of de minimis balances regardless of the age of the account. The allowance for uncollectible accounts at the end of a year includes amounts billed during the current and prior fiscal years.

4. DEBT

BANK NOTE PAYABLE
In May 2020, SDCP arranged to borrow up to $35,000,000 through a revolving credit agreement from River City Bank to provide cash for working capital before sufficient revenue is to be collected from customers. The amount available to SDCP “steps up” throughout fiscal year 2022 and will be fully available prior to the end of that year. At June 30, 2021 and 2020, SDCP borrowed a total of $22,840,082 and $990,082, respectively. As security, SDCP assigned a security interest in all accounts, revenues, debt service reserve accounts and cash collateral accounts. Principal can be drawn as needed and interest is accrued on the outstanding balance.

Additionally, the bank requires $5,000,000 cash collateral to be held during the term of the agreement. The stated maturity date is May 31, 2022, with interest payable each month commencing on July 1, 2020. The interest rate at June 30, 2021, was computed at one-month LIBOR plus a rate of 2.00%, for a total rate of approximately 2.10% per annum. In the event of default, the note becomes immediately due and payable.

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 17 4. DEBT (continued)

LOAN PAYABLE
In May 2020, SDCP borrowed $5,000,000 in total from two private lenders for the purpose of funding a collateral account to be held by River City Bank. Each loan is due on May 21, 2023.

The notes bear interest equal to the one-month LIBOR rate plus 2% per annum at June 30, 2021.

Interest payments are due quarterly, commencing when SDCP begins selling electricity to customers. In the event of default, the lender has the right to pursue all remedies available at law or equity against SDCP.

Note and loan principal activity and balances were as follows for the following direct borrowings:

Beginning Additions Payments Ending
Year ended June 30, 2021
Bank note payable 990,082 $ 21,850,000 $ - $ 22,840,082 $ Loans payable 5,000,000 - - 5,000,000
Total 5,990,082 $ 21,850,000 $ - $ 27,840,082
Amounts due within one year 22,840,082
Amounts due after one year 5,000,000 $
Beginning Additions Payments Ending
Period ended June 30, 2020
Bank note payable - $ 990,082 $ - $ 990,082 $
Loans payable - 5,000,000 - 5,000,000
Total - $ 5,990,082 $ - $ 5,990,082
Amounts due within one year -
Amounts due after one year 5,990,082 $
The following is a summary of SDCP’s future annual payment obligations:

Principal Interest Total
Years ended June 30,
2022 22,840,082 $ 544,672 $ 23,384,754 $
2023 5,000,000 94,792 5,094,792
Total 27,840,082 $ 639,464 $ 28,479,546 $

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 18 5. OTHER NONCURRENT LIABILITIES
Included in noncurrent liabilities are amounts advanced by the Cities of San Diego, La Mesa, and Encinitas (the Cities) to SDCP for start-up related costs. SDCP will reimburse the Cities as soon as practically possible and no later than the earlier of five years after SDCP’s formation date of October 1, 2019, or two years after initial loans and lines of credit are repaid. Interest does not accrue on the liabilities to the Cities.

The following is a schedule of changes in other noncurrent liabilities during the period:

Beginning Additions Payments Ending
Year ended June 30, 2021
Start-up funds
advanced from Cities 477,176 $ 40,565 $ - $ 517,741 $
Total 477,176 $ 40,565 $ - $ 517,741
Amounts due within one year -
Amounts due after one year 517,741 $
Beginning Additions Payments Ending
Period ended June 30, 2020
Start-up funds
advanced from Cities - $ 477,176 $ - $ 477,176 $
Total - $ 477,176 $ - $ 477,176
Amounts due within one year -
Amounts due after one year 477,176 $

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 19 6. RISK MANAGEMENT
SDCP is exposed to various risks of loss related to torts; theft of, damage to, and destruction of assets; and errors and omissions. During the year, SDCP purchased insurance policies from investment-grade commercial carriers to mitigate risks that include those associated with earthquakes, theft, general liability, errors and omissions, and property damage. There were no significant reductions in coverage compared to the prior year. From time to time, SDCP may be party to various pending claims and legal proceedings. Although the outcome of such matters cannot be forecasted with certainty, it is the opinion of management and SDCP’s legal counsel that the likelihood is remote that any such claims or proceedings will have a material adverse effect on SDCP’s financial position or results of operations.

SDCP maintains risk management policies, procedures and systems that help mitigate credit, liquidity, market, operating, regulatory and other risks that arise from participation in the California energy market. Credit guidelines include a preference for transacting with investment-grade counterparties, evaluating counterparties’ financial condition and assigning credit limits as applicable. These credit limits are established based on risk and return considerations under terms customarily available in the industry. In addition, SDCP enters into netting arrangements whenever possible and where appropriate obtains collateral and other performance assurances from counter parties.

7. COMMITMENTS
In the ordinary course of business, SDCP enters into various power purchase agreements in order to acquire renewable and other energy and electric capacity. The price and volume of purchased power may be fixed or variable. Variable pricing is generally based on the market price of either natural gas or electricity at the date of delivery. Variable volume is generally associated with contracts to purchase energy from as-available resources such as solar, wind, and hydro-electric facilities.

The following table represents the expected, undiscounted, contractual obligations outstanding as of June 30, 2021:

Years ending June 30,
2022 259,700,000 $
2023 174,000,000
2024 102,200,000
2025 33,700,000
2026 14,600,000
Total 584,200,000 $

SAN DIEGO COMMUNITY POWER

NOTES TO THE BASIC FINANCIAL STATEMENTS
YEAR ENDED JUNE 30, 2021 AND PERIOD FROM INCEPTION TO JUNE 30, 2020 20 8. FUTURE GASB PRONOUNCEMENTS
The requirements of the following GASB Statements are effective for years ending after June 30, 2021:

GASB has approved GASB Statement No. 87, Leases, GASB 94, Public-Private and Public-Public Partnerships and Availability Payment Arrangements, GASB 96, Subscription-Based Information Technology Arrangements; and GASB No. 97, Certain Component Unit Criteria and Accounting and Financial Reporting for Internal Revenue Code Section 457 Deferred Compensation Plans. The effects of applying these standards are currently unknown.

SAN DIEGO COMMUNITY POWER
Staff Report – Item 4
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Eric W. Washington, Chief Financial Officer
Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Appointment of Director LaCava to the Finance and Risk Management Committee
Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Staff recommends that the Board of Directors appoint Director Joe LaCava to the Finance and Risk Management Committee effective February 1, 2022.

BACKGROUND
Section 5.10.2 of the SDCP Joint Powers Agreement calls for the appointment of a subset of directors to the Finance and Risk Management Committee. To date, SDCP’s Finance and Risk Management Committee has been composed of two committee members.

However, with the recent expansion of the Board to seven Directors, SDCP has the opportunity to appoint an additional committee member.

Article VIII, section 2 of the Bylaws states that the Board Chair nominates members to standing committees, subject to approval by majority vote by the Board.

ANALYSIS AND DISCUSSION
The Board Chair has nominated Director Joe LaCava to the Finance and Risk Management Committee.

COMMITTEE REVIEW
N/A

FISCAL IMPACT
N/A

ATTACHMENTS
N/A

SAN DIEGO COMMUNITY POWER
Staff Report – Item 5
-------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Lucas Utouh, Director of Data Analytics and Account Services Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Update on Back-Office Metrics and Dashboard
Date: January 20, 2022
--------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive update on various back-office activities.

BACKGROUND
Staff will provide regular updates to the Board of Directors regarding San Diego Community Power’s (SDCP) back-office activities centered around tracking opt actions (i.e. opt outs, opt ups and opt downs) as well as customer engagement metrics. The following is a brief overview of items pertaining to back-office operations.

ANALYSIS AND DISCUSSION
A) Phase 3 Enrollment Planning
Staff is happy to report to the Board that our pre-enrollment notice #1 for La Mesa and Net Energy Metering (NEM) customers across all member cities whose true up is in March have been sent out to customers as of 12/30/2021, within the 60 days notification statutory requirement.

Non-NEM – La Mesa:

NEM – Member Cities Excluding Encinitas
NEM – Encinitas (different due to their Power100 default) B) Participation Tracking
SDCP Staff and Calpine have worked together to create a reporting summary of customer actions to opt-out, opt-up to Power100 or opt down from Power100 to PowerOn. The below charts summarize these actions accordingly as of January 09th, 2022:

I. Opt Outs
II. Opt Ups to Power100
III. Opt Downs from Power100 (Encinitas)
IV. Participation Rate.
*For Phase 3, the participation rate will be computed once customers are fully enrolled.

In the interim, we’ll report on the opt outs associated with the phase on a rolling basis as of the reporting month:

C) Contact Center Metrics
We are also tracking customer interactions via our Calpine Contact Center and the chart below summarizes contact made by customers broken down by month through January 9th, 2021:

COMMITTEE REVIEW
N/A

FISCAL IMPACT
N/A

ATTACHMENTS
N/A

SAN DIEGO COMMUNITY POWER
Staff Report – Item 6
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Laura Fernandez, Director of Regulatory and Legislative Affairs Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Update on Regulatory and Legislative Affairs
Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive and file update on regulatory and legislative affairs.

BACKGROUND
Staff will provide regular updates to the Board of Directors regarding SDCP’s regulatory and legislative engagement. The following is an overview of this month’s discussion items, which are informational only.

ANALYSIS and DISCUSSION
A) Net Energy Metering 3.0 Proceeding
Background
The Net Energy Metering (NEM) program is designed to support the installation of customer-sited renewable generation. It was originally established in California with the adoption of Senate Bill (SB) 656 (Alquist, Stats. 1995, chi 369), codified in Section 2827 of the Public Utilities Code. Importantly, Public Utilities Code Section 2827.1 only applies to large electrical corporations, and thereby excludes community choice aggregators (CCAs) such as SDCP. This is because CCAs are legally entitled to set their own electricity generation rates. CCAs therefore determine their own rate policies, including NEM and net surplus compensation policies.

Under the original NEM program, customers who install and operate small (1MW or less) renewable generation facilities (referred to as “customer-generators”) may participate.

Previously, under the original NEM rate, customer-generators received a full retail rate bill credit for power generated by their onsite systems that was fed back into the power grid during times when generation exceeded onsite energy demand. These credits were used to offset customers’ electricity bills, and could be rolled over to subsequent bills for up to a year.

AB 327 (Pereda, 2013) directed each large investor-owned utility (IOU) to switch over to the current NEM tariff on July 1, 2017, or after their NEM capacity exceeded 5% aggregated customer peak demand, whichever came first. SDG&E transferred to the current NEM tariff on June 29, 2016. Customer-generators that interconnected their systems to the grid prior to this date were grandfathered into the former NEM rate, pursuant to Decision (D.)14-03-041.  These customer-generators are currently allowed to remain on the former rate for 20 years from the date they interconnected, or they are permitted to switch to the current NEM rate.  The former NEM rate is sometimes referred to as "NEM 1.0", and the current NEM rate as "NEM 2.0" or "NEM Successor Tariff." The current NEM program was adopted by the CPUC in D.16-01-044 on January 28, 2016 and is available to customers of the large investor-owned utilities (IOUs). The program provides customer-generators full retail rate credits for energy exported to the grid and requires them to pay a few charges that align NEM customer costs more closely with non-NEM customer costs.  Any customer-generator applying for NEM will:
• Pay a one-time interconnection fee: Customer-generators with facilities under 1 MW must pay a pre-approved one-time interconnection fee based on each IOU's historic interconnection costs.  SDG&E's is $132. • Pay non-bypassable charges: Customer-generators, similar to other utility customers, will pay charges on each kilowatt-hour (kWh) of electricity they consume from the grid.  These charges fund programs such as low-income and energy efficiency programs.
• Transfer to a time-of-use (TOU) rate.  If a customer-generator is not already on one, they will be required to take service on a time-of-use (TOU) rate to participate in NEM.

NEM 3.0
D.16-01-044 also established the CPUC’s commitment to review the NEM 2.0 tariff in 2019 (or later) citing interactive, yet unresolved, policy movements within the CPUC, but outside the scope of that proceeding. On September 3, 2020 the CPUC initiated a new rulemaking (R.) 20-08-020 in order to address the development of a successor to the existing NEM 2.0 tariffs. This proceeding is known as the NEM 3.0 proceeding. SDCP is a party to the NEM 3.0 rulemaking.

On March 15, 2021, eighteen proposals for a successor to the current NEM tariff were filed by a wide range of parties in the proceeding, including the Joint IOUs, Sierra Club, The Utility Reform Network, Natural Resources Defense Council, Solar Energy Industries Association, Vote Solar, Small Business Utility Advocates, Coalition for Community Solar Access, Protect Our Communities Foundation, GRID Alternatives, among others.

On May 28, 2021, a comparative analysis of the cost-effectiveness of the NEM successor rate proposals prepared by E3 was issued, and an update was released on June 15, 2021. Additionally, opening testimony was filed by parties in the proceeding on June 18, 2021, and rebuttal testimony was submitted July 16. Evidentiary hearings took place from July 26 until August 9. SDCP filed a Reply Brief on September 14, 2021.

On December 13, 2021, the CPUC issued the long awaited Proposed Decision (PD). The following is a summary of the PD, which was presented during the SDCP December Board Meeting:
• The PD agrees with the conclusions from the Lookback Study, including that NEM

2.0 has negatively impacted non-participant ratepayers, NEM 2.0 is not cost-effective and NEM 2.0 disproportionately harms low-income customers not participating in the NEM tariff.
• The PD adopts a Grid Participation Charge of $8/kW, so the typical 6kW system would pay $48 per month, or $576 per year.
o Low-income and tribal homes would be exempt from this Grid Participation Charge.
• The PD also would reduce payments to solar customers when these customers generate more electricity than they need.
o Instead of being compensated at the retail rate, which is the same rate they pay for electricity from the grid, newly enrolled net metering customers would be paid at the much lower “avoided cost” rate.
 That would amount to about 5 cents per kilowatt-hour of electricity, down from 20 to 30 cents today.
• The PD requires existing residential NEM 1.0 and NEM 2.0 customers to transition to the new tariff no later than 15 years after date of interconnection. o However, low-income homes could keep operating under the more favorable terms of the old program for 20 years after installation. • The NEM 2.0 program would sunset 4 months after the final decision. • The PD also establishes a Storage Evolution Fund to encourage homes and businesses that already have solar to add batteries.
o Customers currently enrolled in NEM would receive rebates of $200 per kilowatt-hour for installing an energy storage system — but only if they switch to the new tariff within four years.
 The rebate would drop the longer customers wait.
• The PD also adopts a proposal by the Solar Energy Industries Association and Vote Solar that will allow customers to oversize loads to promote electrification, this would allow homes and businesses to install solar systems big enough to meet 150% of their energy demand, which could help fuel electric cars or electric heating systems they might add later.
o Oversizing is not permitted under the current rules.
• Finally, the PD establishes an Equity Fund to address the low adoption rate of distributed generation in low-income households; there is an annual cap of $150 million, so up to $600 million over the next 4 years.
o The details of this fund will be worked out later through a workshop process.

On January 7, 2022, over thirty parties submitted opening comments in response to the PD. SDCP filed joint comments with East Bay Community Energy (EBCE) and addressed the following points:
• The proposed Grid Participation Charge is illegal under federal law. o Under the Public Utilities Regulatory Policy Act of 1978, rates to qualifying facilities must be nondiscriminatory.
• It is reasonable for NEM customers to pay all non-bypassable charges that are paid by other customers.
o Currently NEM customers are exempted from paying the following charges:
the Wildfire Fund Charge, Reliability Services, New System Generation Costs, IOU securitization costs relating to wildfires.
• The Commission should adopt hourly netting practices rather than netting on an instantaneous basis.
o Unless and until instantaneous data is made available to other key stakeholders including solar installers and CCAs implementing instantaneous netting raises consumer protection concerns and is likely to dampen the growth of solar.
• The Commission should adopt Sierra Club’s glidepath towards an export credit rate based upon electrification rates as a more reasonable approach to adjusting compensation for exported energy than the PD’s approach. o The PD moves to a net billing framework which bases the credit for exported energy on avoided costs as identified in the Commission’s Avoided Cost Calculator, rejecting recommendations to continuing basing the export credit on retail rates; the proposal by Sierra Club bases the export credit rate on electrification rates with modest fixed charges and a glidepath to avoided cost.
• In order to support low-income customers in their adoption of customer-sited distributed generation, the Commission should exempt low-income customers from any fixed charge associated with the electrification rate as part of adopting the Sierra Club’s export compensation rate proposal.
o For example, the fixed charge for SDG&Es EV-TOU-5 rate is $16 per month.

Next Steps:
• Reply Comments will be filed on January 14, 2022
• Oral argument will take place at a date that is yet to be determined • The Commission will vote on a final decision as soon as January 27, 2022 B) Integrated Resource Planning – Modified Cost Allocation Mechanism In 2019 with Decision 19-11-016, the Commission ordered load-serving entities (LSEs) to procure 3,300 MW of System Resource Adequacy (RA) in three separate tranches, with projects to come online in 2021, 2022 and 2023. The resource need was identified for the entire system, and so the Commission concluded that all LSEs serving load at the time should share in the responsibility and be allocated a procurement obligation. That obligation was allocated among LSEs using a combination of load forecast and RA requirements. Cost recovery and other issues, including RA credits, were to be addressed by a modified Cost Allocation Mechanism (mCAM) that was to be developed by the Commission later in time, but a decision on the mCAM has not yet been issued.

Since D.19-11-016 was adopted, SDCP has registered with the Commission, undertaken substantial energy procurement and began serving load. However, since SDCP was not serving load at the time of the decision, SDCP was not allocated any resources. Applying the same allocation methodology from the decision with updated load forecasts and RA requirements, analysis performed by SDCP shows that the resources are now misallocated. To put the misallocation in perspective, had SDCP been serving load (including load from anticipated expansions) and received an allocation of System RA when D. 19-11-016 was issued, its allocation would have been 135 MW, or 46% percent of the allocation that SDG&E received. Without the mCAM, IOUs retain the excess System RA procured under D. 19-11-016 even though the allocation of those resources no longer accurately reflects load share.

The absence of a decision on the mCAM has given rise to several issues. First, because IOUs retain the excess RA procured under D. 19-11-016, but without direction on cost recovery, it is unclear whether they can sell those resources to new LSEs such as SDCP.

Additionally, LSEs such as SDCP who were not named in the decision must procure necessary System RA even though at some point in the future, they may receive RA credits through the mCAM, exposing them to excessive procurement costs. Finally, IOUs will need to recover the costs of procuring the resources through a Commission-approved process, but at present, there is no clear path forward on cost recovery because the Commission has not yet issued a proposed decision establishing the mechanics of the mCAM.

In light of all of these issues, SDCP along with several other similarly situated CCA programs filed a Motion requesting clarification and interim guidance regarding the forthcoming mCAM. SDG&E, Southern California Edison Company and Pacific Gas and Electric Company all filed responses to the motion and agreed that the extended delay in the adoption of the mCAM has given rise to uncertainty and other challenges, and that a final decision is needed as soon as possible to resolve these ongoing issues. However, the IOUs oppose the CCA Programs’ proposed interim order that is intended to provide greater certainty and mitigate these various issues faced by departed load customers. On January 10, 2022, SDCP along with the other CCA Programs filed a reply to address these issues.

The Commission has not yet addressed the motion. SDCP will continue to seek clarity regarding mCAM in the regulatory arena in order to avoid potentially inefficient procurement.

C. Potential Future Changes to the Low Carbon Fuel Standard (LCFS) Program On January 7, 2022, SDCP along with EBCE, Marin Clean Energy, Peninsula Clean Energy Authority, Redwood Coast Energy Authority, Sonoma Clean Power Authority and Silicon Valley Clean Energy Authority (collectively, the “Joint CCAs”) filed comments with the California Air Resources Board (CARB) regarding potential future changes to the LCFS program. The Joint CCAs requested that CARB consider current aspects of the LCFS that limit the ability of CCAs to participate. Specifically, the Joint CCAs submitted the following recommendations:

1. CARB’s rules governing residential incremental charging credits should be modified to better allow the default LSE, such as a CCA, to claim credits associated with the electricity used by CCA customers as a transportation fuel;

2. Revise the Base Credits provision to identify the LSE serving generation to residential load– which may be an Electrical Distribution Utility (EDU) or a CCA – rather than solely the EDU, as the base credit generator;

3. LCFS rules should be changed to ensure that electric vehicle (EV) charging at multi-unit dwellings (MUDs) can be captured through the LCFS program to support broader access to clean transportation for these customers segments, which may be harder to reach;

4. The Joint CCAs seek clarification on how CARB staff propose to modify pathways for the Medium and Heavy-Duty sector to participate in the LCFS program using zero emission vehicles and electricity as a transportation fuel;

5. The Joint CCAs support implementing declining Carbon Intensity targets post-2030 and strengthening interim pre-2030 targets; and

6. Recommend the creation of an Energy Economy Ratio application process.

Next Steps: Additional pre-rulemaking workshops are expected to take place in early 2022.

COMMITTEE REVIEW
N/A

FISCAL IMPACT
N/A

ATTACHMENTS
N/A

SAN DIEGO COMMUNITY POWER
Staff Report – Item 7
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Rita de la Fuente, Director of External Affairs
Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Update on Community Advisory Committee
Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive and File Report

BACKGROUND
The purpose of the San Diego Community Power (SDCP) Community Advisory Committee (CAC) is to advise the SDCP Board of Directors on the operation of its Community Choice Aggregation program, as stated in section 5.10.3 of the SDCP Joint Powers Authority (JPA) Agreement.

ANALYSIS AND DISCUSSION
The CAC held their regular monthly meeting virtually on Friday, January 14, 2022. The following discussion was captured by staff. The recording and agenda can be found on SDCP’s website.

Discuss and Provide Recommendation to the Board on Including CAC Report Update as a Standing Item on the Regular Meeting Agendas of the Board of Directors
The CAC voted unanimously to ask the Board of Directors to include a standing CAC update given by a CAC Member on the Regular Meeting Agendas.

There was no public comment.

Appoint One CAC Representative to Join the CEO Ad Hoc Search Committee The CAC voted unanimously to recommend to the Board of Directors to appoint CAC Member Matthew Vasilakis to the Chief Executive Officer Ad Hoc Search Committee.

There was no public comment.

Receive and Discuss Update on Proposed 2022 Rates
Staff presented proposed 2022 rates.

Questions/comments from CAC:
• How will customer experience be for residents that are enrolled the same time as the proposed rate change?
• The recent UT article on SDG&E rate increase was cited. • Consider different ways of showing number comparisons. • Will customers receive newsletter emails?
• Are inserts allowed in bill mailers?
• What is the messaging capacity with online billing?
There was no public comment.

Receive and Discuss Update on Residential Enrollment Public Relations Staff presented the status of the Residential Enrollment Public Relations strategy.

Questions/comments from CAC:
• Can staff be available to present to community or business groups? During the public comment period, Fabiola Lao called to suggest social media posts be translated into other languages.

Committee Member Announcements
CAC Member Matthew Vasilakis reported that the Community Power Plan Committee was in the selection stage for the firm to conduct the Community Needs Assessment.

CAC Member David Harris reminded CAC Members to help promote the opportunities for new members. Vice-Chair Hammond asked staff to send social media links to CAC to share. Vice-Chair Hammond asked staff to include information about the upcoming San Diego 350 Net Energy Metering event.

COMMITTEE REVIEW
N/A

FISCAL IMPACT
N/A

ATTACHMENTS
N/A

SAN DIEGO COMMUNITY POWER
Staff Report – Item 8
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Rita de la Fuente, Director of External Affairs
Via: Bill Carnahan, Interim Chief Executive Officer
Subject: Residential Enrollment Public Relations Update Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Receive and file update on Phase 3 Marketing and Public Relations (PR) Campaign for residential enrollment.

BACKGROUND
San Diego Community Power (SDCP) is working Civilian, Inc. (Civilian) on an array of marketing activities to drive awareness, spark community engagement, and minimize opt-outs over the coming months during the Phase 3 Residential Enrollment period (Residential Enrollment). The Phase 3 Marketing and PR Campaign began in December with direct mail enrollment notices to residents being enrolled in February and continues with various tactics to educate and engage new customers.

ANALYSIS AND DISCUSSION
SDCP’s Residential Enrollment campaign is off to a positive start. Below is an overview of how we are building momentum as we prepare to launch in February.

City Engagement
SDCP Staff has met with Events and Communications teams from each city to collaborate on creative ways to reach communities where residential enrollment will soon take place.

SDCP is scheduling presentations to city councils prior to their city’s enrollment. City staff and leaders have shown overwhelming enthusiasm and support in helping SDCP make the greatest impact among their citizens. We will invite our respective Board member from each city to participate in the presentations.

Public Engagement Events
SDCP has recently participated in the following outreach events:
12/8/21 Business For Good Booth and Award Presenter
12/10/21 Climate Action Plan Community Choice Energy Forum 1/6/22 San Diego Better Business Bureau Presentation
1/9/22 Cyclovia Encinitas Booth
SDCP is tentatively scheduled to participate in the following upcoming outreach:
1/22/22 Imperial Beach Small Business Saturday
1/30/22 American Lung Association LUNG FORCE WALK Educational Booth 2/5/22 Imperial Beach Clean-up
3/4/22 La Mesa Farmer’s Market
Staff is constantly looking for ways to engage the community and stakeholders continue to contact SDCP for participation. SDCP Board of Directors, the Community Advisory Committee, and Member Agency staff have been crucial resources in tapping into these opportunities.

My Reasons Creative Concept
Kim Rivero Frink was SDCP’s first business leader and resident to be featured in the My Reasons Campaign, which will be used in print, and social media. Ms. Rivero Frink is representing Imperial Beach as the Board President of SunCoast Market Co-Op. She is an ideal subject because she believes in providing consumers and her community with accessibility to sustainable choices. SDCP will be featuring a local representative for each of the communities that are being enrolled in this phase.

Did You Know Social Media Series
Staff has developed a series of fast facts to be featured on SDCP’s social media channels during Residential Enrollment. These are brief explanations of the basic principles of SDCP and includes responses to frequently asked questions. These posts will be disseminated throughout the Residential Enrollment campaign and beyond.

Bill Explainer Video
Coinciding with the timeline for Residential Enrollment, Staff commissioned and managed the design and development of a bill explainer video that has been posted to our website in English and Spanish. The animated video is a comprehensive walk-through of what SDCP’s customers can expect to see on their bill as an SDCP customer, including all SDG&E charges. The video will be shared on social media and e-newsletters during Residential Enrollment.

Paid Media
City-specific media will run for two months per city, starting a week prior to Residential Enrollment and run during the month of the rollout and three weeks following. This schedule will coincide with the timing of when people get their bills to continue to build awareness and combat any customer anxiety over bill changes.

In addition to culturally diverse publications such as El Latino and Voice & Viewpoint which were included in the Phase 2 campaign, SDCP will have added presence in the Filipino Press, Nquoi Viet Tu Do, San Diego Chinese Tribune, and other smaller community publications.

SDCP and Civilian have also incorporated a few new tactics to reach a broader base of residential customers. Nextdoor has been added to the social media strategy to access local conversions and build brand reputation among neighbors. Billboard advertising and convenience store posters have also been introduced, providing an outdoor presence in communities with less access to online technology.

Communications and Outreach Strategy
PR strategies will ramp up in February 2022 with press releases and outreach to local, state, and national media when Residential Enrollment is launched. Editorials are also being planned for each individual city. The local media has already begun to cover SDCP’s planned activity. Recently, SDCP was featured as one of the Union-Tribune’s top 5 business stories to watch in 2022.

SDCP’s Board of Directors, Community Advisory Committee members and other ambassadors will receive a partner toolkit, an email with links to assets such as prepared social media posts, our logo, and fact sheets that will facilitate the ease sharing communications and gaining support. Finally, at the end of the enrollment phase, SDCP looks forward to sharing the combined impact of the five city launches. Staff and Civilian are working on a celebratory event to reveal a successful Residential Enrollment and our region’s overall progress in June 2022, as well as tactics to keep people engaged beyond the Phase 3 enrollment period.

COMMITTEE REVIEW
This item was reviewed by the Community Advisory Committee on January 14, 2022.

FISCAL IMPACT
N/A

ATTACHMENTS
N/A

SAN DIEGO COMMUNITY POWER
Staff Report – Item 9
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Ryan Baron, General Counsel
Subject: Election of Chair and Vice Chair for Calendar Year 2022 Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Elect a Chair and Vice Chair for Calendar Year 2022

BACKGROUND
Section 5.2 of SDCP’s Joint Powers Agreement (“JPA Agreement”) provides that the Board of Directors will annually elect a Chair and Vice Chair from among its members.

Under the original version of SDCP’s JPA Agreement, the Chair and Vice Chair were elected to serve during each fiscal year (July 1–June 30). At the Board’s December 16, 2021 meeting, the Board approved an amended and restated version of the JPA Agreement, including an amendment to Section 5.2. The Board will now elect a Chair and Vice Chair at its first meeting of each calendar year. The change was made to better align with the timing of Member Agencies’ appointments to the Board.

ANALYSIS AND DISCUSSION
The Board previously held an election for Chair and Vice Chair on August 26, 2021, with the expectation that the elected Chair and Vice Chair serve through June 30, 2022. With the above-described change to the JPA Agreement, the Board is now required to hold an election for the Chair and Vice Chair at its first meeting of 2022. Under the JPA Agreement, the elected Chair and Vice Chair will serve for one year or until a successor is elected. There is no limit on the number of terms the Chair or Vice Chair may serve.

FISCAL IMPACT
None

ATTACHMENTS
None

SAN DIEGO COMMUNITY POWER
Staff Report – Item 10
--------------------------------------------------------------------------------------------------------------------- To: San Diego Community Power Board of Directors
From: Cody Hooven, Chief Operating Officer
Lucas Utouh, Director of Data Analytics and Account Services John Dalessi, Pacific Energy Advisors, Inc
Via: Bill Carnahan, Interim CEO
Subject: Approval of 2022 Rates
Date: January 20, 2022
---------------------------------------------------------------------------------------------------------------------

RECOMMENDATION
Approve the rates contained in Attachment A to be effective as of February 1, 2022.

BACKGROUND
Prior to San Diego Community Power’s (SDCP) launch and initial enrollment of customers in March 2021, customers received bundled electric service (both generation and delivery) from SDG&E under a wide variety of rate schedules. As customers transition into SDCP service, they become “un-bundled”, effectively splitting the charge between SDG&E for transmission/delivery services, and SDCP for generation services. For ease in customer understanding and comparison to SDG&E, SDCP mirrors SDG&E rate schedule structure including time-of-use periods.

Since June 2021, SDCP’s rates include a 1% generation savings relative to SDG&E for customers with a planned reserve margin of at least 5% yield. In comparison, SDG&E also adjusted rates in June 2021, again in November 2021, and most recently as of January 1, 2022. The latest rate change is largely due to significantly higher market power costs affecting all market participants. SDCP is also impacted by the increase in cost of market power supply in 2022, which necessitates an adjustment to our rates to ensure that our fiscal sustainability goals and prudent reserve targets are met. Per our Financial Reserves Policy adopted by the Board in June 2021, SDCP will allocate up to 15% of gross revenue annually toward building an Operating/Working Capital Reserve equivalent to 90 days of total operating expenses (including power supply expenses) to be held as unrestricted cash.

Understanding the need to remain cost competitive, and the many broader financial pressures our customers face, SDCP’s proposed rate change before the Board to be effective as of February 1, 2022, will be at an enhanced savings of 2% for our base product, i.e. PowerOn, compared to SDG&E’s base product while offering a substantially higher renewable energy content. Consistent with good ratemaking practices and as required in our Financial Reserves Policy, rates should, at a minimum, meet the annual revenue requirements developed by SDCP, including any reserves or coverage requirements set forth in policy and/or loan covenants as well as debt service to operate a viable enterprise.

ANALYSIS AND DISCUSSION
SDCP 2022 Rate Setting Mechanics
SDCP utilized the Fiscal Year 2022 proforma benchmark for rate-setting analysis purposes, meaning that the proposed rates were designed to recover a revenue requirement consistent with estimated FY 2022 sales and expenditures. The proposed rates were carefully designed to yield revenues sufficient to collect SDCP’s projected increased annual power supply and other operating costs, debt service costs, plus a planned reserve margin contribution of approximately 7.65%. Per our Board approved Financial Reserves Policy in June, SDCP will allocate up to 15% of gross revenue annually toward building an Operating/Working Capital Reserve equivalent to 90 days of total operating expenses (including power supply expenses) to be held as unrestricted cash.

Critically, these proposed rates were designed to aid in sustaining accrual of reserves to provide a buffer against unplanned variances in revenues and/or operating costs in FY 2022 and beyond. The below chart summarizes a proforma analysis associated with the proposed rates effective as of 2/1/2022:

Recommended Adjustment and Increased Value Proposition Compared to SDG&E.

Our proposed February 2022 rates would increase our value proposition to a 2% generation savings compared to SDG&E , provide reserves of approximately 7.65%, and projected revenues of $386.7 million for the remainder of FY 2022. These proposed rates take into account projected operating costs based on contracts SDCP has executed to date and the projected increased costs of procuring energy and other wholesale services needed to supply SDCP’s customers with a default resource mix of 50% renewable energy and an additional 5% greenhouse gas free power as well as our 100% renewable and renewable energy service.

The SDCP rates for PowerOn (i.e. base portfolio offering) match SDG&E’s rates in terms of rate schedules, time-of-use periods, and mix of energy and demand charges. This rate design approach is typical for CCA programs and has the advantages of ensuring ease of comparison for customers and compatibility with SDG&E’s billing process.

For customers electing the Power100, our 100% renewable energy portfolio offering, an additional charge of 0.0075 cents per kWh will still apply. This premium is based on the estimated incremental cost to SDCP of offering a 100% renewable energy product relative to the default PowerOn product. The SDCP Power100 service would add approximately 4% net impact to a customer’s total electric bill (including SDCP generation charges and SDG&E delivery charges).

As discussed at the December 2021 Board meeting, there is a substantial difference between the Power Charge Indifference Adjustment (PCIA) from last year and this year.

The PCIA is the above market cost of power associated with SDG&E’s portfolio that both SDG&E’s bundled customers as well as SDCP customers who have departed SDG&E commodity service pay. A customer is assigned a PCIA “vintage” based on the year they depart service from the utility. The proposed rates will be bifurcated between our Phase 1 and 2 customers enrolled in 2021 and our Phase 3 customers enrolling this year. This bifurcation will maintain a fair, equitable and balanced rate structure across our customers with differing vintage years that maintains the proposed cost savings for all customers.

Summary
Overall, the proposed rates for 2022 provide the following benefits for SDCP customers and the organization:
• Customer savings are maintained or increased from 1% to 2% • Higher renewable content (base product: 50% with SDCP vs 31% with SDG&E) • Power100 significantly lower cost than SDG&E’s EcoChoice product • Community Power Plan and other programs are underway to provide additional benefits to customers
• 2022 contributions towards reserves will maintain financial stability • Prepares SDCP for 2023 expected market/costs shifts and unexpected costs • Satisfies credit obligations

COMMITTEE REVIEW
This item was reviewed by the Community Advisory Committee on January 14, 2022.

FISCAL IMPACT
Adoption of the updated rates would yield projected revenues of $386.7 million during the current fiscal year ending June 30, 2022.

ATTACHMENTS
Attachment A: SDCP Rates Effective February 1, 2022
Rates effective February 1, 2022
CCA Rate Name Season Charge Type Time of Use Period PowerOn Power100 DR Summer Generation - 2020 Vintage Total $0.19045 + $0.0075 DR Winter Generation - 2020 Vintage Total $0.05541 + $0.0075 DR-LI-MB Summer Generation - 2020 Vintage Total $0.19045 + $0.0075 DR-LI-MB Winter Generation - 2020 Vintage Total $0.05541 + $0.0075 E-LI-TOU Summer Generation - 2020 Vintage Total $0.04758 + $0.0075 E-LI-TOU Winter Generation - 2020 Vintage Total $0.04332 + $0.0075 E-LI-NR Summer Generation - 2020 Vintage Total $0.05518 + $0.0075 E-LI-NR Winter Generation - 2020 Vintage Total $0.05045 + $0.0075 DR-SES Summer Generation - 2020 Vintage On-Peak $0.35781 + $0.0075 DR-SES Summer Generation - 2020 Vintage Off-Peak $0.10729 + $0.0075 DR-SES Summer Generation - 2020 Vintage Super Off-Peak $0.03000 + $0.0075 DR-SES Winter Generation - 2020 Vintage On-Peak $0.12987 + $0.0075 DR-SES Winter Generation - 2020 Vintage Off-Peak $0.08221 + $0.0075 DR-SES Winter Generation - 2020 Vintage Super Off-Peak $0.02379 + $0.0075 EV-TOU Summer Generation - 2020 Vintage On-Peak $0.35781 + $0.0075 EV-TOU Summer Generation - 2020 Vintage Off-Peak $0.10729 + $0.0075 EV-TOU Summer Generation - 2020 Vintage Super Off-Peak $0.03000 + $0.0075 EV-TOU Winter Generation - 2020 Vintage On-Peak $0.12987 + $0.0075 EV-TOU Winter Generation - 2020 Vintage Off-Peak $0.08221 + $0.0075 EV-TOU Winter Generation - 2020 Vintage Super Off-Peak $0.02379 + $0.0075 EV-TOU-2 Summer Generation - 2020 Vintage On-Peak $0.35781 + $0.0075 EV-TOU-2 Summer Generation - 2020 Vintage Off-Peak $0.10729 + $0.0075 EV-TOU-2 Summer Generation - 2020 Vintage Super Off-Peak $0.03000 + $0.0075 EV-TOU-2 Winter Generation - 2020 Vintage On-Peak $0.12987 + $0.0075 EV-TOU-2 Winter Generation - 2020 Vintage Off-Peak $0.08221 + $0.0075 EV-TOU-2 Winter Generation - 2020 Vintage Super Off-Peak $0.02379 + $0.0075 EV-TOU-5 Summer Generation - 2020 Vintage On-Peak $0.35781 + $0.0075 EV-TOU-5 Summer Generation - 2020 Vintage Off-Peak $0.10729 + $0.0075 EV-TOU-5 Summer Generation - 2020 Vintage Super Off-Peak $0.03000 + $0.0075 EV-TOU-5 Winter Generation - 2020 Vintage On-Peak $0.12987 + $0.0075 EV-TOU-5 Winter Generation - 2020 Vintage Off-Peak $0.08221 + $0.0075 EV-TOU-5 Winter Generation - 2020 Vintage Super Off-Peak $0.02379 + $0.0075 TOU-DR-1 Summer Generation - 2020 Vintage On-Peak $0.38754 + $0.0075 TOU-DR-1 Summer Generation - 2020 Vintage Off-Peak $0.15313 + $0.0075 TOU-DR-1 Summer Generation - 2020 Vintage Super Off-Peak $0.03000 + $0.0075 TOU-DR-1 Winter Generation - 2020 Vintage On-Peak $0.10534 + $0.0075 TOU-DR-1 Winter Generation - 2020 Vintage Off-Peak $0.04214 + $0.0075 TOU-DR-1 Winter Generation - 2020 Vintage Super Off-Peak $0.02379 + $0.0075 TOU-DR-2 Summer Generation - 2020 Vintage On-Peak $0.38754 + $0.0075 TOU-DR-2 Summer Generation - 2020 Vintage Off-Peak $0.10236 + $0.0075 TOU-DR-2 Winter Generation - 2020 Vintage On-Peak $0.10534 + $0.0075 TOU-DR-2 Winter Generation - 2020 Vintage Off-Peak $0.03370 + $0.0075 TOU-DR Summer Generation - 2020 Vintage On-Peak $0.26105 + $0.0075 TOU-DR Summer Generation - 2020 Vintage Off-Peak $0.18916 + $0.0075 TOU-DR Summer Generation - 2020 Vintage Super Off-Peak $0.11126 + $0.0075 TOU-DR Winter Generation - 2020 Vintage On-Peak $0.10454 + $0.0075 TOU-DR Winter Generation - 2020 Vintage Off-Peak $0.04168 + $0.0075 TOU-DR Winter Generation - 2020 Vintage Super Off-Peak $0.02344 + $0.0075 TOU-A-S Summer Generation - 2020 Vintage On-Peak $0.22084 + $0.0075 TOU-A-S Summer Generation - 2020 Vintage Off-Peak $0.10687 + $0.0075 TOU-A-S Winter Generation - 2020 Vintage On-Peak $0.11633 + $0.0075 TOU-A-S Winter Generation - 2020 Vintage Off-Peak $0.04066 + $0.0075 TOU-A-P Summer Generation - 2020 Vintage On-Peak $0.21957 + $0.0075 TOU-A-P Summer Generation - 2020 Vintage Off-Peak $0.10617 + $0.0075 TOU-A-P Winter Generation - 2020 Vintage On-Peak $0.11562 + $0.0075 TOU-A-P Winter Generation - 2020 Vintage Off-Peak $0.04038 + $0.0075 TOU-A-2-S Summer Generation - 2020 Vintage On-Peak $0.31103 + $0.0075 TOU-A-2-S Summer Generation - 2020 Vintage Off-Peak $0.08533 + $0.0075 TOU-A-2-S Summer Generation - 2020 Vintage Super Off-Peak $0.03356 + $0.0075 TOU-A-2-S Winter Generation - 2020 Vintage On-Peak $0.10490 + $0.0075 TOU-A-2-S Winter Generation - 2020 Vintage Off-Peak $0.04494 + $0.0075 TOU-A-2-S Winter Generation - 2020 Vintage Super Off-Peak $0.02740 + $0.0075 TOU-A-2-P Summer Generation - 2020 Vintage On-Peak $0.30938 + $0.0075 TOU-A-2-P Summer Generation - 2020 Vintage Off-Peak $0.08479 + $0.0075 TOU-A-2-P Summer Generation - 2020 Vintage Super Off-Peak $0.03334 + $0.0075 TOU-A-2-P Winter Generation - 2020 Vintage On-Peak $0.10428 + $0.0075 TOU-A-2-P Winter Generation - 2020 Vintage Off-Peak $0.04462 + $0.0075 TOU-A-2-P Winter Generation - 2020 Vintage Super Off-Peak $0.02720 + $0.0075 TOU-A-3-S Summer Generation - 2020 Vintage On-Peak $0.22470 + $0.0075 TOU-A-3-S Summer Generation - 2020 Vintage Off-Peak $0.12413 + $0.0075 TOU-A-3-S Summer Generation - 2020 Vintage Super Off-Peak $0.03448 + $0.0075 TOU-A-3-S Winter Generation - 2020 Vintage On-Peak $0.10490 + $0.0075 TOU-A-3-S Winter Generation - 2020 Vintage Off-Peak $0.04494 + $0.0075 TOU-A-3-S Winter Generation - 2020 Vintage Super Off-Peak $0.02740 + $0.0075 TOU-A-3-P Summer Generation - 2020 Vintage On-Peak $0.22346 + $0.0075 TOU-A-3-P Summer Generation - 2020 Vintage Off-Peak $0.12338 + $0.0075 TOU-A-3-P Summer Generation - 2020 Vintage Super Off-Peak $0.03417 + $0.0075 TOU-A-3-P Winter Generation - 2020 Vintage On-Peak $0.10428 + $0.0075 TOU-A-3-P Winter Generation - 2020 Vintage Off-Peak $0.04462 + $0.0075 TOU-A-3-P Winter Generation - 2020 Vintage Super Off-Peak $0.02720 + $0.0075 A-TC Summer Generation - 2020 Vintage Total $0.05001 + $0.0075 A-TC Winter Generation - 2020 Vintage Total $0.05001 + $0.0075 TOU-M Summer Generation - 2020 Vintage On-Peak $0.31256 + $0.0075 TOU-M Summer Generation - 2020 Vintage Off-Peak $0.08541 + $0.0075 TOU-M Summer Generation - 2020 Vintage Super Off-Peak $0.03382 + $0.0075 TOU-M Winter Generation - 2020 Vintage On-Peak $0.10485 + $0.0075 TOU-M Winter Generation - 2020 Vintage Off-Peak $0.04489 + $0.0075 TOU-M Winter Generation - 2020 Vintage Super Off-Peak $0.02735 + $0.0075 OL-TOU Summer Generation - 2020 Vintage On-Peak $0.37649 + $0.0075 OL-TOU Summer Generation - 2020 Vintage Off-Peak $0.10386 + $0.0075 OL-TOU Summer Generation - 2020 Vintage Super Off-Peak $0.04064 + $0.0075 OL-TOU Winter Generation - 2020 Vintage On-Peak $0.12570 + $0.0075 OL-TOU Winter Generation - 2020 Vintage Off-Peak $0.05433 + $0.0075 OL-TOU Winter Generation - 2020 Vintage Super Off-Peak $0.03363 + $0.0075 AL-TOU-S Summer Demand - 2020 Vintage On-Peak $12.29
AL-TOU-S Summer Generation - 2020 Vintage On-Peak $0.14368 + $0.0075 AL-TOU-S Summer Generation - 2020 Vintage Off-Peak $0.06855 + $0.0075 AL-TOU-S Summer Generation - 2020 Vintage Super Off-Peak $0.06385 + $0.0075 AL-TOU-S Winter Generation - 2020 Vintage On-Peak $0.17440 + $0.0075 AL-TOU-S Winter Generation - 2020 Vintage Off-Peak $0.08163 + $0.0075 AL-TOU-S Winter Generation - 2020 Vintage Super Off-Peak $0.05474 + $0.0075 AL-TOU-P Summer Demand - 2020 Vintage On-Peak $12.23
AL-TOU-P Summer Generation - 2020 Vintage On-Peak $0.14281 + $0.0075 AL-TOU-P Summer Generation - 2020 Vintage Off-Peak $0.06806 + $0.0075 AL-TOU-P Summer Generation - 2020 Vintage Super Off-Peak $0.06351 + $0.0075 AL-TOU-P Winter Generation - 2020 Vintage On-Peak $0.17344 + $0.0075 AL-TOU-P Winter Generation - 2020 Vintage Off-Peak $0.08115 + $0.0075 AL-TOU-P Winter Generation - 2020 Vintage Super Off-Peak $0.05444 + $0.0075 AL-TOU-T Summer Demand - 2020 Vintage On-Peak $11.71
AL-TOU-T Summer Generation - 2020 Vintage On-Peak $0.13513 + $0.0075 AL-TOU-T Summer Generation - 2020 Vintage Off-Peak $0.06360 + $0.0075 AL-TOU-T Summer Generation - 2020 Vintage Super Off-Peak $0.05947 + $0.0075 AL-TOU-T Winter Generation - 2020 Vintage On-Peak $0.16458 + $0.0075 AL-TOU-T Winter Generation - 2020 Vintage Off-Peak $0.07630 + $0.0075 AL-TOU-T Winter Generation - 2020 Vintage Super Off-Peak $0.05076 + $0.0075 AL-TOU-2-S Summer Demand - 2020 Vintage On-Peak $22.75
AL-TOU-2-S Summer Generation - 2020 Vintage On-Peak $0.12583 + $0.0075 AL-TOU-2-S Summer Generation - 2020 Vintage Off-Peak $0.05786 + $0.0075 AL-TOU-2-S Summer Generation - 2020 Vintage Super Off-Peak $0.05435 + $0.0075 AL-TOU-2-S Winter Generation - 2020 Vintage On-Peak $0.15446 + $0.0075 AL-TOU-2-S Winter Generation - 2020 Vintage Off-Peak $0.07045 + $0.0075 AL-TOU-2-S Winter Generation - 2020 Vintage Super Off-Peak $0.04609 + $0.0075 AL-TOU-2-P Summer Demand - 2020 Vintage On-Peak $22.65
AL-TOU-2-P Summer Generation - 2020 Vintage On-Peak $0.12506 + $0.0075 AL-TOU-2-P Summer Generation - 2020 Vintage Off-Peak $0.05742 + $0.0075 AL-TOU-2-P Summer Generation - 2020 Vintage Super Off-Peak $0.05404 + $0.0075 AL-TOU-2-P Winter Generation - 2020 Vintage On-Peak $0.15358 + $0.0075 AL-TOU-2-P Winter Generation - 2020 Vintage Off-Peak $0.07001 + $0.0075 AL-TOU-2-P Winter Generation - 2020 Vintage Super Off-Peak $0.04582 + $0.0075 AL-TOU-2-T Summer Demand - 2020 Vintage On-Peak $21.68
AL-TOU-2-T Summer Generation - 2020 Vintage On-Peak $0.11813 + $0.0075 AL-TOU-2-T Summer Generation - 2020 Vintage Off-Peak $0.05342 + $0.0075 AL-TOU-2-T Summer Generation - 2020 Vintage Super Off-Peak $0.05038 + $0.0075 AL-TOU-2-T Winter Generation - 2020 Vintage On-Peak $0.14556 + $0.0075 AL-TOU-2-T Winter Generation - 2020 Vintage Off-Peak $0.06563 + $0.0075 AL-TOU-2-T Winter Generation - 2020 Vintage Super Off-Peak $0.04250 + $0.0075 DG-R-S Summer Generation - 2020 Vintage On-Peak $0.37776 + $0.0075 DG-R-S Summer Generation - 2020 Vintage Off-Peak $0.10289 + $0.0075 DG-R-S Summer Generation - 2020 Vintage Super Off-Peak $0.04057 + $0.0075 DG-R-S Winter Generation - 2020 Vintage On-Peak $0.12565 + $0.0075 DG-R-S Winter Generation - 2020 Vintage Off-Peak $0.05430 + $0.0075 DG-R-S Winter Generation - 2020 Vintage Super Off-Peak $0.03362 + $0.0075 DG-R-P Summer Generation - 2020 Vintage On-Peak $0.37570 + $0.0075 DG-R-P Summer Generation - 2020 Vintage Off-Peak $0.10223 + $0.0075 DG-R-P Summer Generation - 2020 Vintage Super Off-Peak $0.04030 + $0.0075 DG-R-P Winter Generation - 2020 Vintage On-Peak $0.12490 + $0.0075 DG-R-P Winter Generation - 2020 Vintage Off-Peak $0.05392 + $0.0075 DG-R-P Winter Generation - 2020 Vintage Super Off-Peak $0.03339 + $0.0075 DG-R-T Summer Generation - 2020 Vintage On-Peak $0.35736 + $0.0075 DG-R-T Summer Generation - 2020 Vintage Off-Peak $0.09614 + $0.0075 DG-R-T Summer Generation - 2020 Vintage Super Off-Peak $0.03720 + $0.0075 DG-R-T Winter Generation - 2020 Vintage On-Peak $0.11809 + $0.0075 DG-R-T Winter Generation - 2020 Vintage Off-Peak $0.05020 + $0.0075 DG-R-T Winter Generation - 2020 Vintage Super Off-Peak $0.03056 + $0.0075 A6-TOU-P Summer Demand - 2020 Vintage Total $12.23
A6-TOU-P Summer Generation - 2020 Vintage On-Peak $0.14281 + $0.0075 A6-TOU-P Summer Generation - 2020 Vintage Off-Peak $0.06806 + $0.0075 A6-TOU-P Summer Generation - 2020 Vintage Super Off-Peak $0.06351 + $0.0075 A6-TOU-P Winter Generation - 2020 Vintage On-Peak $0.17344 + $0.0075 A6-TOU-P Winter Generation - 2020 Vintage Off-Peak $0.08115 + $0.0075 A6-TOU-P Winter Generation - 2020 Vintage Super Off-Peak $0.05444 + $0.0075 A6-TOU-T Summer Demand - 2020 Vintage Total $11.71
A6-TOU-T Summer Generation - 2020 Vintage On-Peak $0.13513 + $0.0075 A6-TOU-T Summer Generation - 2020 Vintage Off-Peak $0.06360 + $0.0075 A6-TOU-T Summer Generation - 2020 Vintage Super Off-Peak $0.05947 + $0.0075 A6-TOU-T Winter Generation - 2020 Vintage On-Peak $0.16458 + $0.0075 A6-TOU-T Winter Generation - 2020 Vintage Off-Peak $0.07630 + $0.0075 A6-TOU-T Winter Generation - 2020 Vintage Super Off-Peak $0.05076 + $0.0075 TOU-PA-S Summer Generation - 2020 Vintage On-Peak $0.22541 + $0.0075 TOU-PA-S Summer Generation - 2020 Vintage Off-Peak $0.11284 + $0.0075 TOU-PA-S Winter Generation - 2020 Vintage On-Peak $0.10439 + $0.0075 TOU-PA-S Winter Generation - 2020 Vintage Off-Peak $0.03746 + $0.0075 TOU-PA-P Summer Generation - 2020 Vintage On-Peak $0.22416 + $0.0075 TOU-PA-P Summer Generation - 2020 Vintage Off-Peak $0.11214 + $0.0075 TOU-PA-P Winter Generation - 2020 Vintage On-Peak $0.10377 + $0.0075 TOU-PA-P Winter Generation - 2020 Vintage Off-Peak $0.03723 + $0.0075 TOU-PA-2-S Summer Demand - 2020 Vintage On-Peak $10.94
TOU-PA-2-S Summer Generation - 2020 Vintage On-Peak $0.12222 + $0.0075 TOU-PA-2-S Summer Generation - 2020 Vintage Off-Peak $0.06563 + $0.0075 TOU-PA-2-S Summer Generation - 2020 Vintage Super Off-Peak $0.04433 + $0.0075 TOU-PA-2-S Winter Generation - 2020 Vintage On-Peak $0.12176 + $0.0075 TOU-PA-2-S Winter Generation - 2020 Vintage Off-Peak $0.05679 + $0.0075 TOU-PA-2-S Winter Generation - 2020 Vintage Super Off-Peak $0.03794 + $0.0075 TOU-PA-2-P Summer Demand - 2020 Vintage On-Peak $10.89
TOU-PA-2-P Summer Generation - 2020 Vintage On-Peak $0.12159 + $0.0075 TOU-PA-2-P Summer Generation - 2020 Vintage Off-Peak $0.06526 + $0.0075 TOU-PA-2-P Summer Generation - 2020 Vintage Super Off-Peak $0.04409 + $0.0075 TOU-PA-2-P Winter Generation - 2020 Vintage On-Peak $0.12108 + $0.0075 TOU-PA-2-P Winter Generation - 2020 Vintage Off-Peak $0.05644 + $0.0075 TOU-PA-2-P Winter Generation - 2020 Vintage Super Off-Peak $0.03773 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2020 Vintage On-Peak $0.26299 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2020 Vintage Off-Peak $0.13029 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2020 Vintage Super Off-Peak $0.04840 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2020 Vintage On-Peak $0.09508 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2020 Vintage Off-Peak $0.04182 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2020 Vintage Super Off-Peak $0.02638 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2020 Vintage On-Peak $0.26159 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2020 Vintage Off-Peak $0.12953 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2020 Vintage Super Off-Peak $0.04804 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2020 Vintage On-Peak $0.09452 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2020 Vintage Off-Peak $0.04154 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2020 Vintage Super Off-Peak $0.02620 + $0.0075 TOU-PA-3-S >=20kW Summer Demand - 2020 Vintage On-Peak $2.98 TOU-PA-3-S >=20kW Summer Generation - 2020 Vintage On-Peak $0.25104 + $0.0075 TOU-PA-3-S >=20kW Summer Generation - 2020 Vintage Off-Peak $0.12326 + $0.0075 TOU-PA-3-S >=20kW Summer Generation - 2020 Vintage Super Off-Peak $0.04119 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2020 Vintage On-Peak $0.08953 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2020 Vintage Off-Peak $0.03872 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2020 Vintage Super Off-Peak $0.02398 + $0.0075 TOU-PA-3-P >=20kW Summer Demand - 2020 Vintage On-Peak $2.98 TOU-PA-3-P >=20kW Summer Generation - 2020 Vintage On-Peak $0.24978 + $0.0075 TOU-PA-3-P >=20kW Summer Generation - 2020 Vintage Off-Peak $0.12260 + $0.0075 TOU-PA-3-P >=20kW Summer Generation - 2020 Vintage Super Off-Peak $0.04087 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2020 Vintage On-Peak $0.08898 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2020 Vintage Off-Peak $0.03841 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2020 Vintage Super Off-Peak $0.02374 + $0.0075 PA-T-1-S Summer Demand - 2020 Vintage On-Peak $6.21
PA-T-1-S Summer Generation - 2020 Vintage On-Peak $0.12466 + $0.0075 PA-T-1-S Summer Generation - 2020 Vintage Off-Peak $0.06744 + $0.0075 PA-T-1-S Summer Generation - 2020 Vintage Super Off-Peak $0.04908 + $0.0075 PA-T-1-S Winter Generation - 2020 Vintage On-Peak $0.13176 + $0.0075 PA-T-1-S Winter Generation - 2020 Vintage Off-Peak $0.06240 + $0.0075 PA-T-1-S Winter Generation - 2020 Vintage Super Off-Peak $0.04227 + $0.0075 PA-T-1-P Summer Demand - 2020 Vintage On-Peak $6.18
PA-T-1-P Summer Generation - 2020 Vintage On-Peak $0.12393 + $0.0075 PA-T-1-P Summer Generation - 2020 Vintage Off-Peak $0.06701 + $0.0075 PA-T-1-P Summer Generation - 2020 Vintage Super Off-Peak $0.04883 + $0.0075 PA-T-1-P Winter Generation - 2020 Vintage On-Peak $0.13103 + $0.0075 PA-T-1-P Winter Generation - 2020 Vintage Off-Peak $0.06203 + $0.0075 PA-T-1-P Winter Generation - 2020 Vintage Super Off-Peak $0.04205 + $0.0075 PA-T-1-T Summer Demand - 2020 Vintage On-Peak $5.92
PA-T-1-T Summer Generation - 2020 Vintage On-Peak $0.11748 + $0.0075 PA-T-1-T Summer Generation - 2020 Vintage Off-Peak $0.06305 + $0.0075 PA-T-1-T Summer Generation - 2020 Vintage Super Off-Peak $0.04581 + $0.0075 PA-T-1-T Winter Generation - 2020 Vintage On-Peak $0.12440 + $0.0075 PA-T-1-T Winter Generation - 2020 Vintage Off-Peak $0.05841 + $0.0075 PA-T-1-T Winter Generation - 2020 Vintage Super Off-Peak $0.03930 + $0.0075 LS All Generation - 2020 Vintage Total $0.07046 + $0.0075 OL-2 All Generation - 2020 Vintage Total $0.07046 + $0.0075 LS-2-AD Summer Generation - 2020 Vintage On-Peak $0.23335 + $0.0075 LS-2-AD Summer Generation - 2020 Vintage Off-Peak $0.13278 + $0.0075 LS-2-AD Summer Generation - 2020 Vintage Super Off-Peak $0.04313 + $0.0075 LS-2-AD Winter Generation - 2020 Vintage On-Peak $0.11355 + $0.0075 LS-2-AD Winter Generation - 2020 Vintage Off-Peak $0.05359 + $0.0075 LS-2-AD Winter Generation - 2020 Vintage Super Off-Peak $0.03605 + $0.0075 G-DR-SES Summer Generation - 2020 Vintage On-Peak $0.22397 + $0.0075 G-DR-SES Summer Generation - 2020 Vintage Semi-Peak $0.22392 + $0.0075 G-DR-SES Summer Generation - 2020 Vintage Off-Peak $0.22391 + $0.0075 G-DR-SES Winter Generation - 2020 Vintage Semi-Peak $0.24177 + $0.0075 G-DR-SES Winter Generation - 2020 Vintage Off-Peak $0.24176 + $0.0075 G-EV-TOU Summer Generation - 2020 Vintage On-Peak $0.12097 + $0.0075 G-EV-TOU Summer Generation - 2020 Vintage Off-Peak $0.12095 + $0.0075 G-EV-TOU Summer Generation - 2020 Vintage Super Off-Peak $0.09473 + $0.0075 G-EV-TOU Winter Generation - 2020 Vintage On-Peak $0.09692 + $0.0075 G-EV-TOU Winter Generation - 2020 Vintage Off-Peak $0.09691 + $0.0075 G-EV-TOU Winter Generation - 2020 Vintage Super Off-Peak $0.06210 + $0.0075 G-EV-TOU-2 Summer Generation - 2020 Vintage On-Peak $0.16022 + $0.0075 G-EV-TOU-2 Summer Generation - 2020 Vintage Off-Peak $0.16020 + $0.0075 G-EV-TOU-2 Summer Generation - 2020 Vintage Super Off-Peak $0.16019 + $0.0075 G-EV-TOU-2 Winter Generation - 2020 Vintage On-Peak $0.39862 + $0.0075 G-EV-TOU-2 Winter Generation - 2020 Vintage Off-Peak $0.14774 + $0.0075 G-EV-TOU-2 Winter Generation - 2020 Vintage Super Off-Peak $0.14773 + $0.0075 G-TOU-DR Summer Generation - 2020 Vintage On-Peak $0.32438 + $0.0075 G-TOU-DR Summer Generation - 2020 Vintage Semi-Peak $0.20003 + $0.0075 G-TOU-DR Summer Generation - 2020 Vintage Off-Peak $0.14292 + $0.0075 G-TOU-DR Winter Generation - 2020 Vintage On-Peak $0.13877 + $0.0075 G-TOU-DR Winter Generation - 2020 Vintage Semi-Peak $0.04298 + $0.0075 G-TOU-DR Winter Generation - 2020 Vintage Off-Peak $0.04297 + $0.0075 G-TOU-M Summer Generation - 2020 Vintage On-Peak $0.13278 + $0.0075 G-TOU-M Summer Generation - 2020 Vintage Semi-Peak $0.13085 + $0.0075 G-TOU-M Summer Generation - 2020 Vintage Off-Peak $0.13060 + $0.0075 G-TOU-M Winter Generation - 2020 Vintage On-Peak $0.13775 + $0.0075 G-TOU-M Winter Generation - 2020 Vintage Semi-Peak $0.04782 + $0.0075 G-TOU-M Winter Generation - 2020 Vintage Off-Peak $0.04761 + $0.0075 G-OL-TOU Summer Generation - 2020 Vintage On-Peak $0.06329 + $0.0075 G-OL-TOU Summer Generation - 2020 Vintage Semi-Peak $0.07992 + $0.0075 G-OL-TOU Summer Generation - 2020 Vintage Off-Peak $0.09282 + $0.0075 G-OL-TOU Winter Generation - 2020 Vintage On-Peak $0.26348 + $0.0075 G-OL-TOU Winter Generation - 2020 Vintage Semi-Peak $0.10397 + $0.0075 G-OL-TOU Winter Generation - 2020 Vintage Off-Peak $0.10395 + $0.0075 G-TOU-A-S Summer Generation - 2020 Vintage On-Peak $0.25813 + $0.0075 G-TOU-A-S Summer Generation - 2020 Vintage Semi-Peak $0.13301 + $0.0075 G-TOU-A-S Summer Generation - 2020 Vintage Off-Peak $0.04312 + $0.0075 G-TOU-A-S Winter Generation - 2020 Vintage On-Peak $0.13474 + $0.0075 G-TOU-A-S Winter Generation - 2020 Vintage Semi-Peak $0.04641 + $0.0075 G-TOU-A-S Winter Generation - 2020 Vintage Off-Peak $0.04621 + $0.0075 G-TOU-A-P Summer Generation - 2020 Vintage On-Peak $0.25660 + $0.0075 G-TOU-A-P Summer Generation - 2020 Vintage Semi-Peak $0.13214 + $0.0075 G-TOU-A-P Summer Generation - 2020 Vintage Off-Peak $0.04272 + $0.0075 G-TOU-A-P Winter Generation - 2020 Vintage On-Peak $0.13394 + $0.0075 G-TOU-A-P Winter Generation - 2020 Vintage Semi-Peak $0.04608 + $0.0075 G-TOU-A-P Winter Generation - 2020 Vintage Off-Peak $0.04586 + $0.0075 G-AL-TOU-S Summer Demand - 2020 Vintage On-Peak $0.18
G-AL-TOU-S Summer Generation - 2020 Vintage On-Peak $0.06020 + $0.0075 G-AL-TOU-S Summer Generation - 2020 Vintage Semi-Peak $0.06102 + $0.0075 G-AL-TOU-S Summer Generation - 2020 Vintage Off-Peak $0.07015 + $0.0075 G-AL-TOU-S Winter Generation - 2020 Vintage On-Peak $0.29521 + $0.0075 G-AL-TOU-S Winter Generation - 2020 Vintage Semi-Peak $0.11883 + $0.0075 G-AL-TOU-S Winter Generation - 2020 Vintage Off-Peak $0.11883 + $0.0075 G-AL-TOU-P Summer Demand - 2020 Vintage On-Peak $0.18
G-AL-TOU-P Summer Generation - 2020 Vintage On-Peak $0.05969 + $0.0075 G-AL-TOU-P Summer Generation - 2020 Vintage Semi-Peak $0.06049 + $0.0075 G-AL-TOU-P Summer Generation - 2020 Vintage Off-Peak $0.06958 + $0.0075 G-AL-TOU-P Winter Generation - 2020 Vintage On-Peak $0.29360 + $0.0075 G-AL-TOU-P Winter Generation - 2020 Vintage Semi-Peak $0.11814 + $0.0075 G-AL-TOU-P Winter Generation - 2020 Vintage Off-Peak $0.11815 + $0.0075 G-AL-TOU-T Summer Demand - 2020 Vintage On-Peak $0.17
G-AL-TOU-T Summer Generation - 2020 Vintage On-Peak $0.05542 + $0.0075 G-AL-TOU-T Summer Generation - 2020 Vintage Semi-Peak $0.05616 + $0.0075 G-AL-TOU-T Summer Generation - 2020 Vintage Off-Peak $0.06486 + $0.0075 G-AL-TOU-T Winter Generation - 2020 Vintage On-Peak $0.27944 + $0.0075 G-AL-TOU-T Winter Generation - 2020 Vintage Semi-Peak $0.11169 + $0.0075 G-AL-TOU-T Winter Generation - 2020 Vintage Off-Peak $0.11170 + $0.0075 G-DG-R-S Summer Generation - 2020 Vintage On-Peak $0.06482 + $0.0075 G-DG-R-S Summer Generation - 2020 Vintage Semi-Peak $0.07879 + $0.0075 G-DG-R-S Summer Generation - 2020 Vintage Off-Peak $0.09274 + $0.0075 G-DG-R-S Winter Generation - 2020 Vintage On-Peak $0.26343 + $0.0075 G-DG-R-S Winter Generation - 2020 Vintage Semi-Peak $0.10393 + $0.0075 G-DG-R-S Winter Generation - 2020 Vintage Off-Peak $0.10394 + $0.0075 G-DG-R-P Summer Generation - 2020 Vintage On-Peak $0.06419 + $0.0075 G-DG-R-P Summer Generation - 2020 Vintage Semi-Peak $0.07816 + $0.0075 G-DG-R-P Summer Generation - 2020 Vintage Off-Peak $0.09206 + $0.0075 G-DG-R-P Winter Generation - 2020 Vintage On-Peak $0.26197 + $0.0075 G-DG-R-P Winter Generation - 2020 Vintage Semi-Peak $0.10331 + $0.0075 G-DG-R-P Winter Generation - 2020 Vintage Off-Peak $0.10332 + $0.0075 G-DG-R-T Summer Generation - 2020 Vintage On-Peak $0.05890 + $0.0075 G-DG-R-T Summer Generation - 2020 Vintage Semi-Peak $0.07283 + $0.0075 G-DG-R-T Summer Generation - 2020 Vintage Off-Peak $0.08634 + $0.0075 G-DG-R-T Winter Generation - 2020 Vintage On-Peak $0.24917 + $0.0075 G-DG-R-T Winter Generation - 2020 Vintage Semi-Peak $0.09749 + $0.0075 G-DG-R-T Winter Generation - 2020 Vintage Off-Peak $0.09749 + $0.0075 G-A6-TOU-P Summer Demand - 2020 Vintage Total $0.18
G-A6-TOU-P Summer Generation - 2020 Vintage On-Peak $0.05969 + $0.0075 G-A6-TOU-P Summer Generation - 2020 Vintage Semi-Peak $0.06049 + $0.0075 G-A6-TOU-P Summer Generation - 2020 Vintage Off-Peak $0.06958 + $0.0075 G-A6-TOU-P Winter Generation - 2020 Vintage On-Peak $0.29360 + $0.0075 G-A6-TOU-P Winter Generation - 2020 Vintage Semi-Peak $0.11814 + $0.0075 G-A6-TOU-P Winter Generation - 2020 Vintage Off-Peak $0.11815 + $0.0075 G-A6-TOU-T Summer Demand - 2020 Vintage Total $0.17
G-A6-TOU-T Summer Generation - 2020 Vintage On-Peak $0.05542 + $0.0075 G-A6-TOU-T Summer Generation - 2020 Vintage Semi-Peak $0.05616 + $0.0075 G-A6-TOU-T Summer Generation - 2020 Vintage Off-Peak $0.06486 + $0.0075 G-A6-TOU-T Winter Generation - 2020 Vintage On-Peak $0.27944 + $0.0075 G-A6-TOU-T Winter Generation - 2020 Vintage Semi-Peak $0.11169 + $0.0075 G-A6-TOU-T Winter Generation - 2020 Vintage Off-Peak $0.11170 + $0.0075 G-PA-T-1-S Summer Demand - 2020 Vintage On-Peak $1.10
G-PA-T-1-S Summer Generation - 2020 Vintage On-Peak $0.06523 + $0.0075 G-PA-T-1-S Summer Generation - 2020 Vintage Semi-Peak $0.06453 + $0.0075 G-PA-T-1-S Summer Generation - 2020 Vintage Off-Peak $0.05255 + $0.0075 G-PA-T-1-S Winter Generation - 2020 Vintage On-Peak $0.20467 + $0.0075 G-PA-T-1-S Winter Generation - 2020 Vintage Semi-Peak $0.08205 + $0.0075 G-PA-T-1-S Winter Generation - 2020 Vintage Off-Peak $0.08203 + $0.0075 G-PA-T-1-P Summer Demand - 2020 Vintage On-Peak $1.10
G-PA-T-1-P Summer Generation - 2020 Vintage On-Peak $0.06042 + $0.0075 G-PA-T-1-P Summer Generation - 2020 Vintage Semi-Peak $0.05973 + $0.0075 G-PA-T-1-P Summer Generation - 2020 Vintage Off-Peak $0.04780 + $0.0075 G-PA-T-1-P Winter Generation - 2020 Vintage On-Peak $0.20355 + $0.0075 G-PA-T-1-P Winter Generation - 2020 Vintage Semi-Peak $0.08157 + $0.0075 G-PA-T-1-P Winter Generation - 2020 Vintage Off-Peak $0.08156 + $0.0075 G-PA-T-1-T Summer Demand - 2020 Vintage On-Peak $1.05
G-PA-T-1-T Summer Generation - 2020 Vintage On-Peak $0.06072 + $0.0075 G-PA-T-1-T Summer Generation - 2020 Vintage Semi-Peak $0.06008 + $0.0075 G-PA-T-1-T Summer Generation - 2020 Vintage Off-Peak $0.04867 + $0.0075 G-PA-T-1-T Winter Generation - 2020 Vintage On-Peak $0.20224 + $0.0075 G-PA-T-1-T Winter Generation - 2020 Vintage Semi-Peak $0.08101 + $0.0075 G-PA-T-1-T Winter Generation - 2020 Vintage Off-Peak $0.08099 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2020 Vintage On-Peak $0.30124 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2020 Vintage Semi-Peak $0.12054 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2020 Vintage Off-Peak $0.05826 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2020 Vintage On-Peak $0.11718 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2020 Vintage Semi-Peak $0.04104 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2020 Vintage Off-Peak $0.04103 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2020 Vintage On-Peak $0.29951 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2020 Vintage Semi-Peak $0.11977 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2020 Vintage Off-Peak $0.05782 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2020 Vintage On-Peak $0.11643 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2020 Vintage Semi-Peak $0.04069 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2020 Vintage Off-Peak $0.04067 + $0.0075 G-TOU-PA-S >= 20kW Summer Demand - 2020 Vintage On-Peak $1.41 G-TOU-PA-S >= 20kW Summer Generation - 2020 Vintage On-Peak $0.07303 + $0.0075 G-TOU-PA-S >= 20kW Summer Generation - 2020 Vintage Semi-Peak $0.06973 + $0.0075 G-TOU-PA-S >= 20kW Summer Generation - 2020 Vintage Off-Peak $0.05624 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2020 Vintage On-Peak $0.22352 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2020 Vintage Semi-Peak $0.09088 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2020 Vintage Off-Peak $0.09086 + $0.0075 G-TOU-PA-P >= 20kW Summer Demand - 2020 Vintage On-Peak $1.41000 G-TOU-PA-P >= 20kW Summer Generation - 2020 Vintage On-Peak $0.07258 + $0.0075 G-TOU-PA-P >= 20kW Summer Generation - 2020 Vintage Semi-Peak $0.06929 + $0.0075 G-TOU-PA-P >= 20kW Summer Generation - 2020 Vintage Off-Peak $0.05594 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2020 Vintage On-Peak $0.22230 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2020 Vintage Semi-Peak $0.09037 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2020 Vintage Off-Peak $0.09035 + $0.0075 Rates effective February 1, 2022
CCA Rate Name Season Charge Type Time of Use Period PowerOn ($/kWh) Power100 ($/kWh) DR Summer Generation - 2021 Vintage Total $0.20074 + $0.0075 DR Winter Generation - 2021 Vintage Total $0.06570 + $0.0075 DR-LI-MB Summer Generation - 2021 Vintage Total $0.20074 + $0.0075 DR-LI-MB Winter Generation - 2021 Vintage Total $0.06570 + $0.0075 E-LI-TOU Summer Generation - 2021 Vintage Total $0.06082 + $0.0075 E-LI-TOU Winter Generation - 2021 Vintage Total $0.05656 + $0.0075 E-LI-NR Summer Generation - 2021 Vintage Total $0.07083 + $0.0075 E-LI-NR Winter Generation - 2021 Vintage Total $0.06610 + $0.0075 DR-SES Summer Generation - 2021 Vintage On-Peak $0.36810 + $0.0075 DR-SES Summer Generation - 2021 Vintage Off-Peak $0.11758 + $0.0075 DR-SES Summer Generation - 2021 Vintage Super Off-Peak $0.04029 + $0.0075 DR-SES Winter Generation - 2021 Vintage On-Peak $0.14016 + $0.0075 DR-SES Winter Generation - 2021 Vintage Off-Peak $0.09250 + $0.0075 DR-SES Winter Generation - 2021 Vintage Super Off-Peak $0.03408 + $0.0075 EV-TOU Summer Generation - 2021 Vintage On-Peak $0.36810 + $0.0075 EV-TOU Summer Generation - 2021 Vintage Off-Peak $0.11758 + $0.0075 EV-TOU Summer Generation - 2021 Vintage Super Off-Peak $0.04029 + $0.0075 EV-TOU Winter Generation - 2021 Vintage On-Peak $0.14016 + $0.0075 EV-TOU Winter Generation - 2021 Vintage Off-Peak $0.09250 + $0.0075 EV-TOU Winter Generation - 2021 Vintage Super Off-Peak $0.03408 + $0.0075 EV-TOU-2 Summer Generation - 2021 Vintage On-Peak $0.36810 + $0.0075 EV-TOU-2 Summer Generation - 2021 Vintage Off-Peak $0.11758 + $0.0075 EV-TOU-2 Summer Generation - 2021 Vintage Super Off-Peak $0.04029 + $0.0075 EV-TOU-2 Winter Generation - 2021 Vintage On-Peak $0.14016 + $0.0075 EV-TOU-2 Winter Generation - 2021 Vintage Off-Peak $0.09250 + $0.0075 EV-TOU-2 Winter Generation - 2021 Vintage Super Off-Peak $0.03408 + $0.0075 EV-TOU-5 Summer Generation - 2021 Vintage On-Peak $0.36810 + $0.0075 EV-TOU-5 Summer Generation - 2021 Vintage Off-Peak $0.11758 + $0.0075 EV-TOU-5 Summer Generation - 2021 Vintage Super Off-Peak $0.04029 + $0.0075 EV-TOU-5 Winter Generation - 2021 Vintage On-Peak $0.14016 + $0.0075 EV-TOU-5 Winter Generation - 2021 Vintage Off-Peak $0.09250 + $0.0075 EV-TOU-5 Winter Generation - 2021 Vintage Super Off-Peak $0.03408 + $0.0075 TOU-DR-1 Summer Generation - 2021 Vintage On-Peak $0.39783 + $0.0075 TOU-DR-1 Summer Generation - 2021 Vintage Off-Peak $0.16342 + $0.0075 TOU-DR-1 Summer Generation - 2021 Vintage Super Off-Peak $0.04029 + $0.0075 TOU-DR-1 Winter Generation - 2021 Vintage On-Peak $0.11563 + $0.0075 TOU-DR-1 Winter Generation - 2021 Vintage Off-Peak $0.05243 + $0.0075 TOU-DR-1 Winter Generation - 2021 Vintage Super Off-Peak $0.03408 + $0.0075 TOU-DR-2 Summer Generation - 2021 Vintage On-Peak $0.39783 + $0.0075 TOU-DR-2 Summer Generation - 2021 Vintage Off-Peak $0.11265 + $0.0075 TOU-DR-2 Winter Generation - 2021 Vintage On-Peak $0.11563 + $0.0075 TOU-DR-2 Winter Generation - 2021 Vintage Off-Peak $0.04399 + $0.0075 TOU-DR Summer Generation - 2021 Vintage On-Peak $0.27134 + $0.0075 TOU-DR Summer Generation - 2021 Vintage Off-Peak $0.19945 + $0.0075 TOU-DR Summer Generation - 2021 Vintage Super Off-Peak $0.12155 + $0.0075 TOU-DR Winter Generation - 2021 Vintage On-Peak $0.11483 + $0.0075 TOU-DR Winter Generation - 2021 Vintage Off-Peak $0.05197 + $0.0075 TOU-DR Winter Generation - 2021 Vintage Super Off-Peak $0.03373 + $0.0075 TOU-A-S Summer Generation - 2021 Vintage On-Peak $0.23408 + $0.0075 TOU-A-S Summer Generation - 2021 Vintage Off-Peak $0.12011 + $0.0075 TOU-A-S Winter Generation - 2021 Vintage On-Peak $0.12957 + $0.0075 TOU-A-S Winter Generation - 2021 Vintage Off-Peak $0.05390 + $0.0075 TOU-A-P Summer Generation - 2021 Vintage On-Peak $0.23281 + $0.0075 TOU-A-P Summer Generation - 2021 Vintage Off-Peak $0.11941 + $0.0075 TOU-A-P Winter Generation - 2021 Vintage On-Peak $0.12886 + $0.0075 TOU-A-P Winter Generation - 2021 Vintage Off-Peak $0.05362 + $0.0075 TOU-A-2-S Summer Generation - 2021 Vintage On-Peak $0.32427 + $0.0075 TOU-A-2-S Summer Generation - 2021 Vintage Off-Peak $0.09857 + $0.0075 TOU-A-2-S Summer Generation - 2021 Vintage Super Off-Peak $0.04680 + $0.0075 TOU-A-2-S Winter Generation - 2021 Vintage On-Peak $0.11814 + $0.0075 TOU-A-2-S Winter Generation - 2021 Vintage Off-Peak $0.05818 + $0.0075 TOU-A-2-S Winter Generation - 2021 Vintage Super Off-Peak $0.04064 + $0.0075 TOU-A-2-P Summer Generation - 2021 Vintage On-Peak $0.32262 + $0.0075 TOU-A-2-P Summer Generation - 2021 Vintage Off-Peak $0.09803 + $0.0075 TOU-A-2-P Summer Generation - 2021 Vintage Super Off-Peak $0.04658 + $0.0075 TOU-A-2-P Winter Generation - 2021 Vintage On-Peak $0.11752 + $0.0075 TOU-A-2-P Winter Generation - 2021 Vintage Off-Peak $0.11752 + $0.0075 TOU-A-2-P Winter Generation - 2021 Vintage Super Off-Peak $0.11752 + $0.0075 TOU-A-3-S Summer Generation - 2021 Vintage On-Peak $0.23794 + $0.0075 TOU-A-3-S Summer Generation - 2021 Vintage Off-Peak $0.13737 + $0.0075 TOU-A-3-S Summer Generation - 2021 Vintage Super Off-Peak $0.04772 + $0.0075 TOU-A-3-S Winter Generation - 2021 Vintage On-Peak $0.11814 + $0.0075 TOU-A-3-S Winter Generation - 2021 Vintage Off-Peak $0.05818 + $0.0075 TOU-A-3-S Winter Generation - 2021 Vintage Super Off-Peak $0.04064 + $0.0075 TOU-A-3-P Summer Generation - 2021 Vintage On-Peak $0.23670 + $0.0075 TOU-A-3-P Summer Generation - 2021 Vintage Off-Peak $0.13662 + $0.0075 TOU-A-3-P Summer Generation - 2021 Vintage Super Off-Peak $0.04741 + $0.0075 TOU-A-3-P Winter Generation - 2021 Vintage On-Peak $0.11752 + $0.0075 TOU-A-3-P Winter Generation - 2021 Vintage Off-Peak $0.05786 + $0.0075 TOU-A-3-P Winter Generation - 2021 Vintage Super Off-Peak $0.04044 + $0.0075 A-TC Summer Generation - 2021 Vintage Total $0.06325 + $0.0075 A-TC Winter Generation - 2021 Vintage Total $0.06325 + $0.0075 TOU-M Summer Generation - 2021 Vintage On-Peak $0.32580 + $0.0075 TOU-M Summer Generation - 2021 Vintage Off-Peak $0.09865 + $0.0075 TOU-M Summer Generation - 2021 Vintage Super Off-Peak $0.04706 + $0.0075 TOU-M Winter Generation - 2021 Vintage On-Peak $0.11809 + $0.0075 TOU-M Winter Generation - 2021 Vintage Off-Peak $0.05813 + $0.0075 TOU-M Winter Generation - 2021 Vintage Super Off-Peak $0.04059 + $0.0075 OL-TOU Summer Generation - 2021 Vintage On-Peak $0.39214 + $0.0075 OL-TOU Summer Generation - 2021 Vintage Off-Peak $0.11951 + $0.0075 OL-TOU Summer Generation - 2021 Vintage Super Off-Peak $0.05629 + $0.0075 OL-TOU Winter Generation - 2021 Vintage On-Peak $0.14135 + $0.0075 OL-TOU Winter Generation - 2021 Vintage Off-Peak $0.06998 + $0.0075 OL-TOU Winter Generation - 2021 Vintage Super Off-Peak $0.04928 + $0.0075 AL-TOU-S Summer Demand - 2021 Vintage On-Peak $12.29
AL-TOU-S Summer Generation - 2021 Vintage On-Peak $0.15933 + $0.0075 AL-TOU-S Summer Generation - 2021 Vintage Off-Peak $0.08420 + $0.0075 AL-TOU-S Summer Generation - 2021 Vintage Super Off-Peak $0.07950 + $0.0075 AL-TOU-S Winter Generation - 2021 Vintage On-Peak $0.19005 + $0.0075 AL-TOU-S Winter Generation - 2021 Vintage Off-Peak $0.09728 + $0.0075 AL-TOU-S Winter Generation - 2021 Vintage Super Off-Peak $0.07039 + $0.0075 AL-TOU-P Summer Demand - 2021 Vintage On-Peak $12.23
AL-TOU-P Summer Generation - 2021 Vintage On-Peak $0.15846 + $0.0075 AL-TOU-P Summer Generation - 2021 Vintage Off-Peak $0.08371 + $0.0075 AL-TOU-P Summer Generation - 2021 Vintage Super Off-Peak $0.07916 + $0.0075 AL-TOU-P Winter Generation - 2021 Vintage On-Peak $0.18909 + $0.0075 AL-TOU-P Winter Generation - 2021 Vintage Off-Peak $0.09680 + $0.0075 AL-TOU-P Winter Generation - 2021 Vintage Super Off-Peak $0.07009 + $0.0075 AL-TOU-T Summer Demand - 2021 Vintage On-Peak $11.71
AL-TOU-T Summer Generation - 2021 Vintage On-Peak $0.15078 + $0.0075 AL-TOU-T Summer Generation - 2021 Vintage Off-Peak $0.07925 + $0.0075 AL-TOU-T Summer Generation - 2021 Vintage Super Off-Peak $0.07512 + $0.0075 AL-TOU-T Winter Generation - 2021 Vintage On-Peak $0.18023 + $0.0075 AL-TOU-T Winter Generation - 2021 Vintage Off-Peak $0.09195 + $0.0075 AL-TOU-T Winter Generation - 2021 Vintage Super Off-Peak $0.06641 + $0.0075 AL-TOU-2-S Summer Demand - 2021 Vintage On-Peak $22.75
AL-TOU-2-S Summer Generation - 2021 Vintage On-Peak $0.14148 + $0.0075 AL-TOU-2-S Summer Generation - 2021 Vintage Off-Peak $0.07351 + $0.0075 AL-TOU-2-S Summer Generation - 2021 Vintage Super Off-Peak $0.07000 + $0.0075 AL-TOU-2-S Winter Generation - 2021 Vintage On-Peak $0.17011 + $0.0075 AL-TOU-2-S Winter Generation - 2021 Vintage Off-Peak $0.08610 + $0.0075 AL-TOU-2-S Winter Generation - 2021 Vintage Super Off-Peak $0.06174 + $0.0075 AL-TOU-2-P Summer Demand - 2021 Vintage On-Peak $22.65
AL-TOU-2-P Summer Generation - 2021 Vintage On-Peak $0.14071 + $0.0075 AL-TOU-2-P Summer Generation - 2021 Vintage Off-Peak $0.07307 + $0.0075 AL-TOU-2-P Summer Generation - 2021 Vintage Super Off-Peak $0.06969 + $0.0075 AL-TOU-2-P Winter Generation - 2021 Vintage On-Peak $0.16923 + $0.0075 AL-TOU-2-P Winter Generation - 2021 Vintage Off-Peak $0.08566 + $0.0075 AL-TOU-2-P Winter Generation - 2021 Vintage Super Off-Peak $0.06147 + $0.0075 AL-TOU-2-T Summer Demand - 2021 Vintage On-Peak $21.68
AL-TOU-2-T Summer Generation - 2021 Vintage On-Peak $0.13378 + $0.0075 AL-TOU-2-T Summer Generation - 2021 Vintage Off-Peak $0.06907 + $0.0075 AL-TOU-2-T Summer Generation - 2021 Vintage Super Off-Peak $0.06603 + $0.0075 AL-TOU-2-T Winter Generation - 2021 Vintage On-Peak $0.16121 + $0.0075 AL-TOU-2-T Winter Generation - 2021 Vintage Off-Peak $0.08128 + $0.0075 AL-TOU-2-T Winter Generation - 2021 Vintage Super Off-Peak $0.05815 + $0.0075 DG-R-S Summer Generation - 2021 Vintage On-Peak $0.39341 + $0.0075 DG-R-S Summer Generation - 2021 Vintage Off-Peak $0.11854 + $0.0075 DG-R-S Summer Generation - 2021 Vintage Super Off-Peak $0.05622 + $0.0075 DG-R-S Winter Generation - 2021 Vintage On-Peak $0.14130 + $0.0075 DG-R-S Winter Generation - 2021 Vintage Off-Peak $0.06995 + $0.0075 DG-R-S Winter Generation - 2021 Vintage Super Off-Peak $0.04927 + $0.0075 DG-R-P Summer Generation - 2021 Vintage On-Peak $0.39135 + $0.0075 DG-R-P Summer Generation - 2021 Vintage Off-Peak $0.11788 + $0.0075 DG-R-P Summer Generation - 2021 Vintage Super Off-Peak $0.05595 + $0.0075 DG-R-P Winter Generation - 2021 Vintage On-Peak $0.14055 + $0.0075 DG-R-P Winter Generation - 2021 Vintage Off-Peak $0.06957 + $0.0075 DG-R-P Winter Generation - 2021 Vintage Super Off-Peak $0.04904 + $0.0075 DG-R-T Summer Generation - 2021 Vintage On-Peak $0.37301 + $0.0075 DG-R-T Summer Generation - 2021 Vintage Off-Peak $0.11179 + $0.0075 DG-R-T Summer Generation - 2021 Vintage Super Off-Peak $0.05285 + $0.0075 DG-R-T Winter Generation - 2021 Vintage On-Peak $0.13374 + $0.0075 DG-R-T Winter Generation - 2021 Vintage Off-Peak $0.06585 + $0.0075 DG-R-T Winter Generation - 2021 Vintage Super Off-Peak $0.04621 + $0.0075 A6-TOU-P Summer Demand - 2021 Vintage Total $12.23
A6-TOU-P Summer Generation - 2021 Vintage On-Peak $0.15846 + $0.0075 A6-TOU-P Summer Generation - 2021 Vintage Off-Peak $0.08371 + $0.0075 A6-TOU-P Summer Generation - 2021 Vintage Super Off-Peak $0.07916 + $0.0075 A6-TOU-P Winter Generation - 2021 Vintage On-Peak $0.18909 + $0.0075 A6-TOU-P Winter Generation - 2021 Vintage Off-Peak $0.09680 + $0.0075 A6-TOU-P Winter Generation - 2021 Vintage Super Off-Peak $0.07009 + $0.0075 A6-TOU-T Summer Demand - 2021 Vintage Total $11.71
A6-TOU-T Summer Generation - 2021 Vintage On-Peak $0.15078 + $0.0075 A6-TOU-T Summer Generation - 2021 Vintage Off-Peak $0.07925 + $0.0075 A6-TOU-T Summer Generation - 2021 Vintage Super Off-Peak $0.07512 + $0.0075 A6-TOU-T Winter Generation - 2021 Vintage On-Peak $0.18023 + $0.0075 A6-TOU-T Winter Generation - 2021 Vintage Off-Peak $0.09195 + $0.0075 A6-TOU-T Winter Generation - 2021 Vintage Super Off-Peak $0.06641 + $0.0075 TOU-PA-S Summer Generation - 2021 Vintage On-Peak $0.23390 + $0.0075 TOU-PA-S Summer Generation - 2021 Vintage Off-Peak $0.12133 + $0.0075 TOU-PA-S Winter Generation - 2021 Vintage On-Peak $0.11288 + $0.0075 TOU-PA-S Winter Generation - 2021 Vintage Off-Peak $0.04595 + $0.0075 TOU-PA-P Summer Generation - 2021 Vintage On-Peak $0.23265 + $0.0075 TOU-PA-P Summer Generation - 2021 Vintage Off-Peak $0.12063 + $0.0075 TOU-PA-P Winter Generation - 2021 Vintage On-Peak $0.11226 + $0.0075 TOU-PA-P Winter Generation - 2021 Vintage Off-Peak $0.04572 + $0.0075 TOU-PA-2-S Summer Demand - 2021 Vintage On-Peak $10.94
TOU-PA-2-S Summer Generation - 2021 Vintage On-Peak $0.13071 + $0.0075 TOU-PA-2-S Summer Generation - 2021 Vintage Off-Peak $0.07412 + $0.0075 TOU-PA-2-S Summer Generation - 2021 Vintage Super Off-Peak $0.05282 + $0.0075 TOU-PA-2-S Winter Generation - 2021 Vintage On-Peak $0.13025 + $0.0075 TOU-PA-2-S Winter Generation - 2021 Vintage Off-Peak $0.06528 + $0.0075 TOU-PA-2-S Winter Generation - 2021 Vintage Super Off-Peak $0.04643 + $0.0075 TOU-PA-2-P Summer Demand - 2021 Vintage On-Peak $10.89
TOU-PA-2-P Summer Generation - 2021 Vintage On-Peak $0.13008 + $0.0075 TOU-PA-2-P Summer Generation - 2021 Vintage Off-Peak $0.07375 + $0.0075 TOU-PA-2-P Summer Generation - 2021 Vintage Super Off-Peak $0.05258 + $0.0075 TOU-PA-2-P Winter Generation - 2021 Vintage On-Peak $0.12957 + $0.0075 TOU-PA-2-P Winter Generation - 2021 Vintage Off-Peak $0.06493 + $0.0075 TOU-PA-2-P Winter Generation - 2021 Vintage Super Off-Peak $0.04622 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2021 Vintage On-Peak $0.27148 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2021 Vintage Off-Peak $0.13878 + $0.0075 TOU-PA-3-S <20kW Summer Generation - 2021 Vintage Super Off-Peak $0.05689 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2021 Vintage On-Peak $0.10357 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2021 Vintage Off-Peak $0.05031 + $0.0075 TOU-PA-3-S <20kW Winter Generation - 2021 Vintage Super Off-Peak $0.03487 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2021 Vintage On-Peak $0.27008 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2021 Vintage Off-Peak $0.13802 + $0.0075 TOU-PA-3-P <20kW Summer Generation - 2021 Vintage Super Off-Peak $0.05653 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2021 Vintage On-Peak $0.10301 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2021 Vintage Off-Peak $0.05003 + $0.0075 TOU-PA-3-P <20kW Winter Generation - 2021 Vintage Super Off-Peak $0.03469 + $0.0075 TOU-PA-3-S >=20kW Summer Demand - 2021 Vintage On-Peak $2.98 TOU-PA-3-S >=20kW Summer Generation - 2021 Vintage On-Peak $0.25953 + $0.0075 TOU-PA-3-S >=20kW Summer Generation - 2021 Vintage Off-Peak $0.13175 + $0.0075 TOU-PA-3-S >=20kW Summer Generation - 2021 Vintage Super Off-Peak $0.04968 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2021 Vintage On-Peak $0.09802 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2021 Vintage Off-Peak $0.04721 + $0.0075 TOU-PA-3-S >=20kW Winter Generation - 2021 Vintage Super Off-Peak $0.03247 + $0.0075 TOU-PA-3-P >=20kW Summer Demand - 2021 Vintage On-Peak $2.98 TOU-PA-3-P >=20kW Summer Generation - 2021 Vintage On-Peak $0.25827 + $0.0075 TOU-PA-3-P >=20kW Summer Generation - 2021 Vintage Off-Peak $0.13109 + $0.0075 TOU-PA-3-P >=20kW Summer Generation - 2021 Vintage Super Off-Peak $0.04936 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2021 Vintage On-Peak $0.09747 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2021 Vintage Off-Peak $0.04690 + $0.0075 TOU-PA-3-P >=20kW Winter Generation - 2021 Vintage Super Off-Peak $0.03223 + $0.0075 PA-T-1-S Summer Demand - 2021 Vintage On-Peak $6.21
PA-T-1-S Summer Generation - 2021 Vintage On-Peak $0.13315 + $0.0075 PA-T-1-S Summer Generation - 2021 Vintage Off-Peak $0.07593 + $0.0075 PA-T-1-S Summer Generation - 2021 Vintage Super Off-Peak $0.05757 + $0.0075 PA-T-1-S Winter Generation - 2021 Vintage On-Peak $0.14025 + $0.0075 PA-T-1-S Winter Generation - 2021 Vintage Off-Peak $0.07089 + $0.0075 PA-T-1-S Winter Generation - 2021 Vintage Super Off-Peak $0.05076 + $0.0075 PA-T-1-P Summer Demand - 2021 Vintage On-Peak $6.18
PA-T-1-P Summer Generation - 2021 Vintage On-Peak $0.13242 + $0.0075 PA-T-1-P Summer Generation - 2021 Vintage Off-Peak $0.07550 + $0.0075 PA-T-1-P Summer Generation - 2021 Vintage Super Off-Peak $0.05732 + $0.0075 PA-T-1-P Winter Generation - 2021 Vintage On-Peak $0.13952 + $0.0075 PA-T-1-P Winter Generation - 2021 Vintage Off-Peak $0.07052 + $0.0075 PA-T-1-P Winter Generation - 2021 Vintage Super Off-Peak $0.05054 + $0.0075 PA-T-1-T Summer Demand - 2021 Vintage On-Peak $5.92
PA-T-1-T Summer Generation - 2021 Vintage On-Peak $0.12597 + $0.0075 PA-T-1-T Summer Generation - 2021 Vintage Off-Peak $0.07154 + $0.0075 PA-T-1-T Summer Generation - 2021 Vintage Super Off-Peak $0.05430 + $0.0075 PA-T-1-T Winter Generation - 2021 Vintage On-Peak $0.13289 + $0.0075 PA-T-1-T Winter Generation - 2021 Vintage Off-Peak $0.06690 + $0.0075 PA-T-1-T Winter Generation - 2021 Vintage Super Off-Peak $0.04779 + $0.0075 LS All Generation - 2021 Vintage Total $0.07847 + $0.0075 OL-2 All Generation - 2021 Vintage Total $0.07847 + $0.0075 LS-2-AD Summer Generation - 2021 Vintage On-Peak $0.24136 + $0.0075 LS-2-AD Summer Generation - 2021 Vintage Off-Peak $0.14079 + $0.0075 LS-2-AD Summer Generation - 2021 Vintage Super Off-Peak $0.05114 + $0.0075 LS-2-AD Winter Generation - 2021 Vintage On-Peak $0.12156 + $0.0075 LS-2-AD Winter Generation - 2021 Vintage Off-Peak $0.06160 + $0.0075 LS-2-AD Winter Generation - 2021 Vintage Super Off-Peak $0.04406 + $0.0075 G-DR-SES Summer Generation - 2021 Vintage On-Peak $0.23426 + $0.0075 G-DR-SES Summer Generation - 2021 Vintage Semi-Peak $0.23421 + $0.0075 G-DR-SES Summer Generation - 2021 Vintage Off-Peak $0.23420 + $0.0075 G-DR-SES Winter Generation - 2021 Vintage Semi-Peak $0.25206 + $0.0075 G-DR-SES Winter Generation - 2021 Vintage Off-Peak $0.25205 + $0.0075 G-EV-TOU Summer Generation - 2021 Vintage On-Peak $0.13126 + $0.0075 G-EV-TOU Summer Generation - 2021 Vintage Off-Peak $0.13124 + $0.0075 G-EV-TOU Summer Generation - 2021 Vintage Super Off-Peak $0.10502 + $0.0075 G-EV-TOU Winter Generation - 2021 Vintage On-Peak $0.10721 + $0.0075 G-EV-TOU Winter Generation - 2021 Vintage Off-Peak $0.10720 + $0.0075 G-EV-TOU Winter Generation - 2021 Vintage Super Off-Peak $0.07239 + $0.0075 G-EV-TOU-2 Summer Generation - 2021 Vintage On-Peak $0.17051 + $0.0075 G-EV-TOU-2 Summer Generation - 2021 Vintage Off-Peak $0.17049 + $0.0075 G-EV-TOU-2 Summer Generation - 2021 Vintage Super Off-Peak $0.17048 + $0.0075 G-EV-TOU-2 Winter Generation - 2021 Vintage On-Peak $0.40891 + $0.0075 G-EV-TOU-2 Winter Generation - 2021 Vintage Off-Peak $0.15803 + $0.0075 G-EV-TOU-2 Winter Generation - 2021 Vintage Super Off-Peak $0.15802 + $0.0075 G-TOU-DR Summer Generation - 2021 Vintage On-Peak $0.33467 + $0.0075 G-TOU-DR Summer Generation - 2021 Vintage Semi-Peak $0.21032 + $0.0075 G-TOU-DR Summer Generation - 2021 Vintage Off-Peak $0.15321 + $0.0075 G-TOU-DR Winter Generation - 2021 Vintage On-Peak $0.14906 + $0.0075 G-TOU-DR Winter Generation - 2021 Vintage Semi-Peak $0.05327 + $0.0075 G-TOU-DR Winter Generation - 2021 Vintage Off-Peak $0.05326 + $0.0075 G-TOU-M Summer Generation - 2021 Vintage On-Peak $0.14602 + $0.0075 G-TOU-M Summer Generation - 2021 Vintage Semi-Peak $0.14409 + $0.0075 G-TOU-M Summer Generation - 2021 Vintage Off-Peak $0.14384 + $0.0075 G-TOU-M Winter Generation - 2021 Vintage On-Peak $0.15099 + $0.0075 G-TOU-M Winter Generation - 2021 Vintage Semi-Peak $0.06106 + $0.0075 G-TOU-M Winter Generation - 2021 Vintage Off-Peak $0.06085 + $0.0075 G-OL-TOU Summer Generation - 2021 Vintage On-Peak $0.07894 + $0.0075 G-OL-TOU Summer Generation - 2021 Vintage Semi-Peak $0.09557 + $0.0075 G-OL-TOU Summer Generation - 2021 Vintage Off-Peak $0.10847 + $0.0075 G-OL-TOU Winter Generation - 2021 Vintage On-Peak $0.27913 + $0.0075 G-OL-TOU Winter Generation - 2021 Vintage Semi-Peak $0.11962 + $0.0075 G-OL-TOU Winter Generation - 2021 Vintage Off-Peak $0.11960 + $0.0075 G-TOU-A-S Summer Generation - 2021 Vintage On-Peak $0.27137 + $0.0075 G-TOU-A-S Summer Generation - 2021 Vintage Semi-Peak $0.14625 + $0.0075 G-TOU-A-S Summer Generation - 2021 Vintage Off-Peak $0.05636 + $0.0075 G-TOU-A-S Winter Generation - 2021 Vintage On-Peak $0.14798 + $0.0075 G-TOU-A-S Winter Generation - 2021 Vintage Semi-Peak $0.05965 + $0.0075 G-TOU-A-S Winter Generation - 2021 Vintage Off-Peak $0.05945 + $0.0075 G-TOU-A-P Summer Generation - 2021 Vintage On-Peak $0.26984 + $0.0075 G-TOU-A-P Summer Generation - 2021 Vintage Semi-Peak $0.14538 + $0.0075 G-TOU-A-P Summer Generation - 2021 Vintage Off-Peak $0.05596 + $0.0075 G-TOU-A-P Winter Generation - 2021 Vintage On-Peak $0.14718 + $0.0075 G-TOU-A-P Winter Generation - 2021 Vintage Semi-Peak $0.05932 + $0.0075 G-TOU-A-P Winter Generation - 2021 Vintage Off-Peak $0.05910 + $0.0075 G-AL-TOU-S Summer Demand - 2021 Vintage On-Peak $0.18
G-AL-TOU-S Summer Generation - 2021 Vintage On-Peak $0.07585 + $0.0075 G-AL-TOU-S Summer Generation - 2021 Vintage Semi-Peak $0.07667 + $0.0075 G-AL-TOU-S Summer Generation - 2021 Vintage Off-Peak $0.08580 + $0.0075 G-AL-TOU-S Winter Generation - 2021 Vintage On-Peak $0.31086 + $0.0075 G-AL-TOU-S Winter Generation - 2021 Vintage Semi-Peak $0.13448 + $0.0075 G-AL-TOU-S Winter Generation - 2021 Vintage Off-Peak $0.13448 + $0.0075 G-AL-TOU-P Summer Demand - 2021 Vintage On-Peak $0.18
G-AL-TOU-P Summer Generation - 2021 Vintage On-Peak $0.07534 + $0.0075 G-AL-TOU-P Summer Generation - 2021 Vintage Semi-Peak $0.07614 + $0.0075 G-AL-TOU-P Summer Generation - 2021 Vintage Off-Peak $0.08523 + $0.0075 G-AL-TOU-P Winter Generation - 2021 Vintage On-Peak $0.30925 + $0.0075 G-AL-TOU-P Winter Generation - 2021 Vintage Semi-Peak $0.13379 + $0.0075 G-AL-TOU-P Winter Generation - 2021 Vintage Off-Peak $0.13380 + $0.0075 G-AL-TOU-T Summer Demand - 2021 Vintage On-Peak $0.17
G-AL-TOU-T Summer Generation - 2021 Vintage On-Peak $0.07107 + $0.0075 G-AL-TOU-T Summer Generation - 2021 Vintage Semi-Peak $0.07181 + $0.0075 G-AL-TOU-T Summer Generation - 2021 Vintage Off-Peak $0.08051 + $0.0075 G-AL-TOU-T Winter Generation - 2021 Vintage On-Peak $0.29509 + $0.0075 G-AL-TOU-T Winter Generation - 2021 Vintage Semi-Peak $0.12734 + $0.0075 G-AL-TOU-T Winter Generation - 2021 Vintage Off-Peak $0.12735 + $0.0075 G-DG-R-S Summer Generation - 2021 Vintage On-Peak $0.08047 + $0.0075 G-DG-R-S Summer Generation - 2021 Vintage Semi-Peak $0.09444 + $0.0075 G-DG-R-S Summer Generation - 2021 Vintage Off-Peak $0.10839 + $0.0075 G-DG-R-S Winter Generation - 2021 Vintage On-Peak $0.27908 + $0.0075 G-DG-R-S Winter Generation - 2021 Vintage Semi-Peak $0.11958 + $0.0075 G-DG-R-S Winter Generation - 2021 Vintage Off-Peak $0.11959 + $0.0075 G-DG-R-P Summer Generation - 2021 Vintage On-Peak $0.07984 + $0.0075 G-DG-R-P Summer Generation - 2021 Vintage Semi-Peak $0.09381 + $0.0075 G-DG-R-P Summer Generation - 2021 Vintage Off-Peak $0.10771 + $0.0075 G-DG-R-P Winter Generation - 2021 Vintage On-Peak $0.27762 + $0.0075 G-DG-R-P Winter Generation - 2021 Vintage Semi-Peak $0.11896 + $0.0075 G-DG-R-P Winter Generation - 2021 Vintage Off-Peak $0.11897 + $0.0075 G-DG-R-T Summer Generation - 2021 Vintage On-Peak $0.07455 + $0.0075 G-DG-R-T Summer Generation - 2021 Vintage Semi-Peak $0.08848 + $0.0075 G-DG-R-T Summer Generation - 2021 Vintage Off-Peak $0.10199 + $0.0075 G-DG-R-T Winter Generation - 2021 Vintage On-Peak $0.26482 + $0.0075 G-DG-R-T Winter Generation - 2021 Vintage Semi-Peak $0.11314 + $0.0075 G-DG-R-T Winter Generation - 2021 Vintage Off-Peak $0.11314 + $0.0075 G-A6-TOU-P Summer Demand - 2021 Vintage Total $0.18
G-A6-TOU-P Summer Generation - 2021 Vintage On-Peak $0.07534 + $0.0075 G-A6-TOU-P Summer Generation - 2021 Vintage Semi-Peak $0.07614 + $0.0075 G-A6-TOU-P Summer Generation - 2021 Vintage Off-Peak $0.08523 + $0.0075 G-A6-TOU-P Winter Generation - 2021 Vintage On-Peak $0.30925 + $0.0075 G-A6-TOU-P Winter Generation - 2021 Vintage Semi-Peak $0.13379 + $0.0075 G-A6-TOU-P Winter Generation - 2021 Vintage Off-Peak $0.13380 + $0.0075 G-A6-TOU-T Summer Demand - 2021 Vintage Total $0.17
G-A6-TOU-T Summer Generation - 2021 Vintage On-Peak $0.07107 + $0.0075 G-A6-TOU-T Summer Generation - 2021 Vintage Semi-Peak $0.07181 + $0.0075 G-A6-TOU-T Summer Generation - 2021 Vintage Off-Peak $0.08051 + $0.0075 G-A6-TOU-T Winter Generation - 2021 Vintage On-Peak $0.29509 + $0.0075 G-A6-TOU-T Winter Generation - 2021 Vintage Semi-Peak $0.12734 + $0.0075 G-A6-TOU-T Winter Generation - 2021 Vintage Off-Peak $0.12735 + $0.0075 G-PA-T-1-S Summer Demand - 2021 Vintage On-Peak $1.10
G-PA-T-1-S Summer Generation - 2021 Vintage On-Peak $0.07372 + $0.0075 G-PA-T-1-S Summer Generation - 2021 Vintage Semi-Peak $0.07302 + $0.0075 G-PA-T-1-S Summer Generation - 2021 Vintage Off-Peak $0.06104 + $0.0075 G-PA-T-1-S Winter Generation - 2021 Vintage On-Peak $0.21316 + $0.0075 G-PA-T-1-S Winter Generation - 2021 Vintage Semi-Peak $0.09054 + $0.0075 G-PA-T-1-S Winter Generation - 2021 Vintage Off-Peak $0.09052 + $0.0075 G-PA-T-1-P Summer Demand - 2021 Vintage On-Peak $1.10
G-PA-T-1-P Summer Generation - 2021 Vintage On-Peak $0.06891 + $0.0075 G-PA-T-1-P Summer Generation - 2021 Vintage Semi-Peak $0.06822 + $0.0075 G-PA-T-1-P Summer Generation - 2021 Vintage Off-Peak $0.05629 + $0.0075 G-PA-T-1-P Winter Generation - 2021 Vintage On-Peak $0.21204 + $0.0075 G-PA-T-1-P Winter Generation - 2021 Vintage Semi-Peak $0.09006 + $0.0075 G-PA-T-1-P Winter Generation - 2021 Vintage Off-Peak $0.09005 + $0.0075 G-PA-T-1-T Summer Demand - 2021 Vintage On-Peak $1.05
G-PA-T-1-T Summer Generation - 2021 Vintage On-Peak $0.06921 + $0.0075 G-PA-T-1-T Summer Generation - 2021 Vintage Semi-Peak $0.06857 + $0.0075 G-PA-T-1-T Summer Generation - 2021 Vintage Off-Peak $0.05716 + $0.0075 G-PA-T-1-T Winter Generation - 2021 Vintage On-Peak $0.21073 + $0.0075 G-PA-T-1-T Winter Generation - 2021 Vintage Semi-Peak $0.08950 + $0.0075 G-PA-T-1-T Winter Generation - 2021 Vintage Off-Peak $0.08948 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2021 Vintage On-Peak $0.30973 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2021 Vintage Semi-Peak $0.12903 + $0.0075 G-TOU-PA-S < 20kW Summer Generation - 2021 Vintage Off-Peak $0.06675 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2021 Vintage On-Peak $0.12567 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2021 Vintage Semi-Peak $0.04953 + $0.0075 G-TOU-PA-S < 20kW Winter Generation - 2021 Vintage Off-Peak $0.04952 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2021 Vintage On-Peak $0.30800 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2021 Vintage Semi-Peak $0.12826 + $0.0075 G-TOU-PA-P < 20kW Summer Generation - 2021 Vintage Off-Peak $0.06631 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2021 Vintage On-Peak $0.12492 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2021 Vintage Semi-Peak $0.04918 + $0.0075 G-TOU-PA-P < 20kW Winter Generation - 2021 Vintage Off-Peak $0.04916 + $0.0075 G-TOU-PA-S >= 20kW Summer Demand - 2021 Vintage On-Peak $1.41 G-TOU-PA-S >= 20kW Summer Generation - 2021 Vintage On-Peak $0.08152 + $0.0075 G-TOU-PA-S >= 20kW Summer Generation - 2021 Vintage Semi-Peak $0.07822 + $0.0075 G-TOU-PA-S >= 20kW Summer Generation - 2021 Vintage Off-Peak $0.06473 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2021 Vintage On-Peak $0.23201 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2021 Vintage Semi-Peak $0.09937 + $0.0075 G-TOU-PA-S >= 20kW Winter Generation - 2021 Vintage Off-Peak $0.09935 + $0.0075 G-TOU-PA-P >= 20kW Summer Demand - 2021 Vintage On-Peak $1.41 G-TOU-PA-P >= 20kW Summer Generation - 2021 Vintage On-Peak $0.08107 + $0.0075 G-TOU-PA-P >= 20kW Summer Generation - 2021 Vintage Semi-Peak $0.07778 + $0.0075 G-TOU-PA-P >= 20kW Summer Generation - 2021 Vintage Off-Peak $0.06443 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2021 Vintage On-Peak $0.23079 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2021 Vintage Semi-Peak $0.09886 + $0.0075 G-TOU-PA-P >= 20kW Winter Generation - 2021 Vintage Off-Peak $0.09884 + $0.0075 Power100 cost = (Usage*PowerOn Rate) + (Usage*Power100 Adder)

GLOSSARY OF TERMS
CAISO – California Independent System Operator - a non-profit independent system operator that oversees the operation of the California bulk electric power system, transmission lines and electricity market generated and transmitted by its members (~80% of California’s electric flow).

Its stated mission is to “operate the grid reliably and efficiently, provide fair and open transmission access, promote environmental stewardship and facilitate effective markets and promote infrastructure development. CAISO is regulated by FERC and governed by a five-member governing board appointed by the governor.

CALCCA – California Community Choice Association – Association made up of Community Choice Aggregation (CCA) groups which represents the interests of California’s community choice electricity providers.

CARB – California Air Resources Board – The CARB is charged with protecting the public from the harmful effects of air pollution and developing programs and actions to fight climate change in California.

CEC – California Energy Commission
CPUC – California Public Utility Commission
C&I – Commercial and Industrial – Business customers
CP – Compliance Period – Time period to become RPS compliant, set by the CPUC (California Public Utilities Commission)
DA – Direct Access – An option that allows eligible customers to purchase their electricity directly from third party providers known as Electric Service Providers (ESP).

DA Cap – the maximum amount of electric usage that may be allocated to Direct Access customers in California, or more specifically, within an Investor-Owned Utility service territory.

DA Lottery – a random drawing by which DA waitlist customers become eligible to enroll in DA service under the currently-applicable Direct Access Cap.

DA Waitlist – customers that have officially registered their interest in becoming a DA customer but are not yet able to enroll in service because of DA cap limitations.

DAC – Disadvantaged Community
DASR – Direct Access Service Request – Request submitted by C&I to become direct access eligible.

Demand - The rate at which electric energy is delivered to or by a system or part of a system, generally expressed in kilowatts (kW), megawatts (MW), or gigawatts (GW), at a given instant or averaged over any designated interval of time. Demand should not be confused with Load or Energy.

DER – Distributed Energy Resource – A small-scale physical or virtual asset (e.g. EV charger, smart thermostat, behind-the-meter solar/storage, energy efficiency) that operates locally and is connected to a larger power grid at the distribution level.

Distribution - The delivery of electricity to the retail customer’s home or business through low voltage distribution lines.

DLAP – Default Load Aggregation Point – In the CAISO’s electricity optimization model, DLAP is the node at which all bids for demand should be submitted and settled. SVCE settles its CAISO load at the PG&E DLAP as SVCE is in the PG&E transmission access charge area.

DR – Demand Response - An opportunity for consumers to play a significant role in the operation of the electric grid by reducing or shifting their electricity usage during peak periods in response to time-based rates or other forms of financial incentives.

DWR – Department of Water Resources – DWR manages California’s water resources, systems, and infrastructure in a responsible, sustainable way.

ELCC – Effective Load Carrying Capacity – The additional load met by an incremental generator while maintaining the same level of system reliability. For solar and wind resources the ELCC is the amount of capacity which can be counted for Resource Adequacy purposes.

EPIC – Electric Program Investment Charge – The EPIC program was created by the CPUC to support investments in clean energy technologies that provide benefits to the electricity ratepayers of PG&E, San Diego Gas & Electric Company (SDG&E), and Southern California Edison Company (SCE)
ERRA – Energy Resource Recovery Account – ERRA proceedings are used to determine fuel and purchased power costs which can be recovered in rates. The utilities do not earn a rate of return on these costs, and only recover actual costs. The costs are forecast for the year ahead. If the actual costs are lower than forecast, then the utility gives money back, and vice versa.

ESP – Energy Service Provider - An energy entity that provides service to a retail or end-use customer.

EV – Electric Vehicle
GHG – Greenhouse gas - water vapor, carbon dioxide, tropospheric ozone, nitrous oxide, methane, and chlorofluorocarbons (CFCs). A gas that causes the atmosphere to trap heat radiating from the earth. The most common GHG is Carbon Dioxide, though Methane and others have this effect as well.

GRC – General Rate Case – Proceedings used to address the costs of operating and maintaining the utility system and the allocation of those costs among customer classes. For California’s three large IOUs, the GRCs are parsed into two phases. Phase I of a GRC determines the total amount the utility is authorized to collect, while Phase II determines the share of the cost each customer class is responsible and the rate schedules for each class. Each large electric utility files a GRC application every three years for review by the Public Advocates Office and interested parties and approval by the CPUC.

GWh – Gigawatt-hour - The unit of energy equal to that expended in one hour at a rate of one billion watts. One GWh equals 1,000 megawatt-hours.

IEP – Independent Energy Producers – California’s oldest and leading nonprofit trade association, representing the interest of developers and operators of independent energy facilities and independent power marketers.

IOU – Investor-Owned Utility – A private electricity and natural gas provider.

IRP – Integrated Resource Plan – A plan which outlines an electric utility’s resource needs in order to meet expected electricity demand long-term.
kW – Kilowatt – Measure of power where power (watts) = voltage (volts) x amperage (amps) and 1 kW = 1000 watts
kWh – Kilowatt-hour – This is a measure of consumption. It is the amount of electricity that is used over some period of time, typically a one-month period for billing purposes. Customers are charged a rate per kWh of electricity used.

LCFS – Low Carbon Fuel Standard – A CARB program designed to encourage the use of cleaner low-carbon fuels in California, encourage the production of those fuels, and therefore, reduce greenhouse gas emissions.

LCR – Local (RA) Capacity Requirements – The amount of Resource Adequacy capacity required to be demonstrated in a specific location or zone.

LMP – Locational Marginal Price – Each generator unit and load pocket is assigned a node in the CAISO optimization model. The model will assign a LMP to the node in both the day- ahead and real time market as it balances the system using the least cost. The LMP is comprised of three components: the marginal cost of energy, congestion and losses. The LMP is used to financially settle transactions in the CAISO.

Load - An end use device or customer that receives power from an energy delivery system. Load should not be confused with Demand, which is the measure of power that a load receives or requires. See Demand.

LSE – Load-serving Entity – Entities that have been granted authority by state, local law or regulation to serve their own load directly through wholesale energy purchases and have chosen to exercise that authority.

NEM – Net Energy Metering – A program in which solar customers receive credit for excess electricity generated by solar panels.

NRDC – Natural Resources Defense Council
OIR – Order Instituting Rulemaking - A procedural document that is issued by the CPUC to start a formal proceeding. A draft OIR is issued for comment by interested parties and made final by vote of the five Commissioners of the CPUC.

MW – Megawatt – measure of power. A megawatt equals 1,000 kilowatts or 1 million watts.

MWH – Megawatt-hour – measure of energy
NP-15 – North Path 15 – NP-15 is a CAISO pricing zone usually used to approximate wholesale electricity prices in northern California in PG&E’s service territory.

PCC1 – RPS Portfolio Content Category 1 – Bundled renewables where the energy and REC are dynamically scheduled into a California Balancing Authority (CBA) such as the CAISO. Also known as “in-state” renewables
PCC2 – RPS Portfolio Content Category 2 – Bundled renewables where the energy and REC are from out-of-state and not dynamically scheduled to a CBA.

PCC3 – RPS Portfolio Content Category 3 – Unbundled REC PCIA or “exit fee” - Power Charge Indifference Adjustment (PCIA) is an “exit fee” based on stranded costs of utility generation set by the California Public Utilities Commission. It is calculated annually and assessed to customers of CCAs and paid to the IOU that lost those customers as a result of the formation of a CCA.

PCL – Power Content Label – A user-friendly way of displaying information to California consumers about the energy resources used to generate the electricity they sell, as required by AB 162 (Statue of 2009) and Senate Bill 1305 (Statutes of 1997).

PD – Proposed Decision – A procedural document in a CPUC Rulemaking process that is formally commented on by Parties to the proceeding. A PD is a precursor to a final Decision voted on by the five Commissioners of the CPUC.

Pnode – Pricing Node – In the CAISO optimization model, it is a point where a physical injection or withdrawal of energy is modeled and for which a LMP is calculated.

PPA – Power Purchase Agreement – A contract used to purchase the energy, capacity and attributes from a renewable resource project.

RA – Resource Adequacy - Under its Resource Adequacy (RA) program, the California Public Utilities Commission (CPUC) requires load-serving entities—both independently owned utilities and electric service providers—to demonstrate in both monthly and annual filings that they have purchased capacity commitments of no less than 115% of their peak loads.

RE – Renewable Energy - Energy from a source that is not depleted when used, such as wind or solar power.

REC - Renewable Energy Certificate - A REC is the property right to the environmental benefits associated with generating renewable electricity. For instance, homeowners who generate solar electricity are credited with 1 solar REC for every MWh of electricity they produce. Utilities obligated to fulfill an RPS requirement can purchase these RECs on the open market.

RPS - Renewable Portfolio Standard - Law that requires CA utilities and other load serving entities (including CCAs) to provide an escalating percentage of CA qualified renewable power (culminating at 33% by 2020) in their annual energy portfolio.

SCE – Southern California Edison
SDG&E – San Diego Gas & Electric
SGIP – Self-Generation Incentive Program – A program which provides incentives to support existing, new, and emerging distributed energy resources (storage, wind turbines, waste heat to power technologies, etc.)
TCR EPS Protocol – The Climate Registry Electric Power Sector Protocol – Online tools and resources provided by The Climate Registry to assist organizations to measure, report, and reduce carbon emissions.

Time-of-Use (TOU) Rates — The pricing of delivered electricity based on the estimated cost of electricity during a particular time-block. Time-of-use rates are usually divided into three or four time-blocks per 24 hour period (on-peak, midpeak, off-peak and sometimes super off-peak) and by seasons of the year (summer and winter). Real time pricing differs from TOU rates in that it is based on actual (as opposed to forecasted) prices that may fluctuate many times a day and are weather sensitive, rather than varying with a fixed schedule.

TURN – The Utility Reform Network - A ratepayer advocacy group charged with ensuring that California IOUs implement just and reasonable rates.

Unbundled RECs - Renewable energy certificates that verify a purchase of a MWH unit of renewable power where the actual power and the certificate are “unbundled” and sold to different buyers.

VPP – Virtual Power Plant – A cloud-based network that leverages an aggregation of distributed energy resources (DERs) to shift energy demand or provide services to the grid. For example, thousands of EV chargers could charge at a slower speed and hundreds of home batteries could discharge to the grid during a demand peak to significantly reduce the procurement of traditional supply resources.

San Diego Community Power Board of DirectorsJanuary 20, 2022

San Diego Community Power Board of Directors
January 20, 2022