Agenda packet — MCE Board of Directors, July 16, 2026

MCE Board of Directors Meeting
Thursday, July 16, 2026
6:30 p.m.
1125 Tamalpais Avenue
San Rafael, CA 94901
2300 Clayton Road, Suite 1500
Concord, CA 94520
Public comments may be made in person or remotely via the details below.

Remote Public Meeting Participation
Video Conference:
https://us02web.zoom.us/j/89004877785?pwd=OTYzWGk4V2ptMFdlVGFScmw3NTlldz09 Phone: Dial (669) 900-9128, Meeting ID: 890 0487 7785, Passcode: 525690 Materials related to this agenda are available for physical inspection at MCE’s offices in San Rafael at 1125 Tamalpais Avenue, San Rafael, CA 94901 and in Concord at 2300 Clayton Road, Suite 1500, Concord, CA 94520.

DISABLED ACCOMMODATION: If you are a person with a disability who requires an accommodation or an alternative format, please contact MCE at (888) 632-3674 or [email protected] at least 72 hours before the meeting start time to ensure arrangements are made.

The Board of Directors may discuss and/or take action on any or all of the items listed on the agenda irrespective of how the items are described.

Agenda Page 1 of 2

1. Roll Call/Quorum

2. Board Announcements (Discussion)

3. Public Open Time (Discussion)

4. Report from Chief Executive Officer (Discussion)
Agenda Page 2 of 2

5. Consent Calendar (Discussion/Action)
C.1. Approval of 6.15.26 Meeting Minutes
C.2. Approval of 6.18.26 Meeting Minutes
C.3. Addition of Board Members to Committees
C.4. MCE Application to the California Energy Commission’s GFO-25- 608 - Electric Vehicle Hub, Outreach, Messaging, and Equipment C.5. Proposed Exception to Operating Reserve Fund Policy Cap and Transfer

6. Integrated Resource Plan (Discussion/Action)

7. Proposed Creation of Ad Hoc CEO Search Committee
(Discussion/Action)

8. Receive Public Comment on the Civil Grand Jury Report (Discussion)

9. Proposed Creation of Ad Hoc Civil Grand Jury Response Committee (Discussion/Action)

10. Proposed General Counsel Reporting Structure (Discussion/Action)

11. Board & Staff Matters (Discussion)

12. Adjourn
Informational Reports
I.1 Approved Contracts for Energy Update
I.2 Legislative and Regulatory Updates
I.3 Customer Programs Update
I.4 Interim Financial Statements Fiscal Year Ended 2026 DRAFT

MCE SPECIAL BOARD MEETING MINUTES
Monday, June 15, 2026
6:30 P.M.

Present: Liz Alessio, County of Napa and Four Napa Cities/Town (American Canyon, Calistoga, St. Helena, and Yountville) Eli Beckman, Town of Corte Madera
Mark Belotz, Town of Danville
Kari Birdseye, City of Benicia
Barbara Coler, Town of Fairfax
Cindy Darling, City of Walnut Creek
Jill Hoffman, City of Sausalito
Kevin Jacobs, City of Novato
Eduardo Martinez, City of Richmond
John McCormick, City of Lafayette
Aaron Meadows, City of Oakley
Laura Nakamura, City of Concord
Beth Painter, City of Napa
Gabe Paulson, Alternate, City of Larkspur
Mary Sackett, County of Marin
Manveer Sandhu, City of Fairfield
Shanelle Scales-Preston, County of Contra Costa, Chair
Sally Wilkinson, City of Belvedere
Brianne Zorn, City of Martinez

Absent: Dion Bailey, City of Hercules
Monica Brown, County of Solano
C. William Kircher, Jr., Town of Ross
Arlene Kobata, City of Pittsburg
Maika Llorens Gulati, City of San Rafael
Devin Murphy, City of Pinole
Charles Palmares, City of Vallejo
Max Perrey, City of Mill Valley
Patricia Ponce, City of San Pablo
Amanda Szakats, City of Pleasant Hill
Graham Thiel, Town of Moraga
Holli Thier, Town of Tiburon
Sridhar Verose, City of San Ramon
Chantel Walker, Town of San Anselmo
Carolyn Wysinger, City of El Cerrito

Staff
& Others: Jesica Brooks, Lead Board Clerk and Executive Assistant DRAFT
Tanya Lomas, Board Clerk
Linda Lye, Senior Legal Counsel
Catalina Murphy, General Counsel
Justine Parmelee, VP of Internal Operations
Enyonam Senyo-Mensah, Manager of Internal Operations

1. Roll Call
(Video 0:00:15)
Chair Scales-Preston called the regular meeting to order at 5:00 p.m. with quorum established by roll call.

2. Public Open Time on Closed Session Matter
(Video 0:03:07)
Chair Scales-Preston opened the public comment period and there were no comments.

Begin Closed Session Chair Scales-Preston opened the closed session at 5:08 p.m.

3. Roll Call/Quorum
(Video 0:05:41)
Chair Scales-Preston returned to open session at 5:56 p.m. and quorum was established by roll call.

General Counsel Murphy stated there was no reportable action and that staff were given directions on next steps.

4. Adjournment
Chair Scales-Preston adjourned the meeting at 5:58 p.m. ___________________________________________
Shanelle Scales-Preston, Chair
Attest:
___________________________________________
Justine Parmelee, Secretary
DRAFT
MCE BOARD MEETING MINUTES1
Thursday, June 18, 2026
6:30 P.M.

Present: Liz Alessio, County of Napa and Four Napa Cities/Town (American Canyon, Calistoga, St. Helena, and Yountville) Stephanie Andre, City of Larkspur
Dion Bailey, City of Hercules
Eli Beckman, Town of Corte Madera
Mark Belotz, Town of Danville
Kari Birdseye, City of Benicia
Monica Brown, County of Solano
Barbara Coler, Town of Fairfax
Jill Hoffman, City of Sausalito
Arlene Kobata, City of Pittsburg
Maika Llorens Gulati, City of San Rafael
Eduardo Martinez, City of Richmond
John McCormick, City of Lafayette
Aaron Meadows, City of Oakley
Laura Nakamura, City of Concord
Beth Painter, City of Napa
Charles Palmares, City of Vallejo, joined at 6:55 p.m.

Max Perrey, City of Mill Valley
Patricia Ponce, City of San Pablo
Mary Sackett, County of Marin
Mathew Salter, Alternate, Town of Ross
Manveer Sandhu, City of Fairfield
Shanelle Scales-Preston, County of Contra Costa, Chair
Sridhar Verose, City of San Ramon
Chantel Walker, Town of San Anselmo
Sally Wilkinson, City of Belvedere
Brianne Zorn, City of Martinez

Absent: Cindy Darling, City of Walnut Creek
Kevin Jacobs, City of Novato
Devin Murphy, City of Pinole
Amanda Szakats, City of Pleasant Hill
Graham Thiel, Town of Moraga
Holli Thier, Town of Tiburon
Carolyn Wysinger, City of El Cerrito
1 Approval of the minutes is a general administrative matter. Action requires a majority vote of board members present for a motion to carry.

DRAFT
Staff
& Others: Jared Blanton, VP of Public Affairs
Jesica Brooks, Lead Board Clerk and Executive Assistant Alcides Hernandez, Director of Rates
Vicken Kasarjian, Acting CEO and Chief Operating Officer Tanya Lomas, Board Clerk
Linda Lye, Senior Legal Counsel
Ashley Muth, Internal Operations Associate
Catalina Murphy, General Counsel
Justine Parmelee, VP of Internal Operations
Mike Rodriguez-Vargas, Internal Operations Assistant
Enyonam Senyo-Mensah, Manager of Internal Operations
Jamie Tuckey, Chief Customer Office

1. Roll Call
Chair Scales-Preston called the regular meeting to order at 6:36 p.m. with quorum established by roll call.

2. Board Announcements (Discussion)
There were comments from Directors Bailey, Nakamura, Zorn, Alessio, and Coler.

3. Public Open Time (Discussion)
Chair Scales-Preston opened the public comment period and there were comments from members of the public Alicia Minyen, Robert Miller, Ron Arlas, and Jody Timms.

4. Report from Chief Executive Officer (Discussion)
Vicken Kasarjian, Acting CEO and Chief Operating Officer, introduced this item and addressed questions from Board members.

Chair Scales-Preston opened the public comment period and there were no comments.

5. Consent Calendar (Discussion/Action)
C.1 Approval of 5.21.26 Meeting Minutes
C.2 Proposed Resolution 2026-04 Amending Resolution 2023-09 Accepting Congressionally Directed Spending Project from the Golden Fields Office of the U.S. Department of Energy and Proposed Agreements with Serious Controls, LLC
Chair Scales-Preston opened the public comment period and there were no comments.

DRAFT
Action: It was M/S/C (Brown/Alessio) to Approve the Consent Calendar.

Motion carried by roll call vote. 29-Yays 1-Abstain (Abstention: Ponce.

Absent: Darling, Jacobs, Murphy, Sandhu, Szakats, Thiel, Thier, and Wysinger).

Chair Scales-Preston moved item 7 to go before item 6.

7. Proposed First Agreement with Leading Resources, Inc for Governance Assessment Services (Discussion/Action)
Chair Scales-Preston, Directors Sackett, Alessio, and Birdseye, introduced this item.

Chair Scales-Preston opened the public comment period and there were no comments.

Action: It was M/S/C (Llorens Gulati/Perrey) to Approve the proposed First Agreement with Leading Resources, Inc. for Governance Assessment Services for an amount not to exceed $103,905 and authorize the acting CEO to execute the Agreement. Motion carried by unanimous roll call vote. (Absent: Darling, Jacobs, Murphy, Szakats, Thiel, Thier, and Wysinger).

6. Proposed Resolution 2026-05 Authorizing Remote Participation at Meetings of the MCE Board and MCE Finance Committee
(Discussion/Action)
Justine Parmelee, VP of Internal Operations, introduced this item and addressed questions from Board members.

Chair Scales-Preston opened the public comment period and there were no comments.

Action: It was M/S/C (Coler/Nakamura) to Approve Resolution 2026-05 Authorizing Remote Participation at meetings of the MCE Board and MCE Finance Committee, as permitted by law. Motion carried by roll call vote. 30-Yays 1-No (No: Brown. Absent: Darling, Jacobs, Murphy, Szakats, Thiel, Thier, and Wysinger).

8. Board & Staff Matters (Discussion)
Director Salter made comments.

9. Adjournment
Chair Scales-Preston adjourned the meeting at 8:11 p.m. to the next scheduled Board Meeting on July 16, 2026.

DRAFT
___________________________________________
Shanelle Scales-Preston, Chair
Attest:
___________________________________________
Justine Parmelee, Secretary
July 16, 2026
TO: MCE Board of Directors
FROM: Jesica Brooks, Executive Assistant and Lead Board Clerk RE: Addition of Board Members to Committees (Agenda Item #05 C.3) ATTACHMENT: 2026 MCE Board Offices and Committee Rosters Dear MCE Board Members:

Summary:

MCE Board Director and City of Belvedere Mayor, Sally Wilkinson, is interested in joining the Interim Advisory Committee.

Fiscal Impacts:

None.

Recommendation:

Approve the 2026 Board & Committee membership as reflected in the Attachment: 2026 MCE Board Offices and Committee Rosters. 1
1 This item is a general administrative matter. Action requires a majority vote of board members present for a motion to carry.

2026 MCE Board Offices and Committee Rosters

BOARD OFFICES
Chair: Shanelle Scales-Preston, County of Contra Costa
Vice Chair: Cindy Darling, Walnut Creek
Treasurer: Maira Strauss, MCE Chief Financial Officer
Secretary: Justine Parmelee, MCE Vice President of Internal Operations

BOARD OFFICES SELECTION PROCESS
The Chair and Vice Chair offices are held for 1 year and there are no limits on the number of terms held by either Chair or Vice Chair.1 The selection of these offices shall take place in or near December of each year.2 The office of Treasurer is appointed by the Board via an approved resolution and may be a non-board member. The Treasurer appointment, along with the delegated authority, is held for 1 year and there are no limits on the number of terms held.3 Deputy Treasurers are appointed directly by the Treasurer each year. Once appointed by the Board, the Secretary shall continue to hold the office each year until the Secretary chooses to resign from the role or the Board decides to remove the individual from the Secretary position.4 The Secretary does not need to be a member of the Board. All officer appointments/selections by the Board require a majority vote of the full membership of the Board.5
EXECUTIVE COMMITTEE (Updated 3.2.26)

1. Barbara Coler, Chair

2. Cindy Darling, Vice Chair

3. Stephanie Andre

4. Kari Birdseye

5. Maika Llorens Gulati

6. Devin Murphy

7. Laura Nakamura

8. Beth Painter

9. Max Perrey

10.Shanelle Scales-Preston

11.Sally Wilkinson
Town of Fairfax
City of Walnut Creek
City of Larkspur
City of Benicia
City of San Rafael
City of Pinole
City of Concord
City of Napa
City of Mill Valley
County of Contra Costa
City of Belvedere
1 Section 4.13.1 of MCE Joint Powers Agreement.
2 Article V, Section 1 of MCE’s Operating Rules and Regulations. 3 Article V, Section 1 of MCE’s Operating Rules and Regulations; California Government Code § 53607. 4 Article IV, Section 1(c) of MCE’s Operating Rules and Regulations. 5 Article VI, Section 2 of MCE’s Operating Rules and Regulations. At MCE’s current membership of 38 communities with appointed Directors, the vote needed is 20.

FINANCE COMMITTEE (Updated 3.26.26)

1. Liz Alessio, Chair

2. John McCormick, Vice Chair

3. Stephanie Andre

4. Charles Palmares

5. Sally Wilkinson
Napa County6
City of Lafayette
City of Larkspur
City of Vallejo
City of Belvedere
TECHNICAL COMMITTEE (Updated 5.21.26)

1. Dion Bailey, Chair

2. Charles Palmares, Vice Chair

3. Devin Murphy

4. Stephanie Andre

5. John McCormick

6. Amanda Szakats

7. Brianne Zorn
City of Hercules
City of Vallejo
City of Pinole
City of Larkspur
City of Lafayette
City of Pleasant Hill
City of Martinez
2026 AD HOC CONTRACTS COMMITTEE (Updated 2.19.26)

1. Barbara Coler

2. Cindy Darling

3. Devin Murphy
Town of Fairfax
City of Walnut Creek
City of Pinole
2026 INTERIM ADVISORY COMMITTEE (Updated 5.21.26)7

1. Cindy Darling

2. John McCormick

3. Devin Murphy

4. Sally Wilkinson, interested
City of Walnut Creek
City of Lafayette
City of Pinole
City of Belvedere
2026 AD HOC GOVERNANCE COMMITTEE (Updated 1.15.26)

1. Liz Alessio

2. Kari Birdseye

3. Mary Sackett

4. Shanelle Scales-Preston
Napa County and Four Napa Cities
City of Benicia
County of Marin
Contra Costa County
6 The Board approved a Finance Committee consisting of 5 to 7 Board representatives. If Director Alessio were to participate in her capacity as the delegate for four Napa Cities, the Finance Committee would effectively have 9 Board representatives, more than the 7 approved by the Board, and Director Alessio would constitute a quorum by herself, raising Brown Act compliance challenges. Given the current size of the Finance Committee, we construe the Board to have appointed Director Alessio to the Committee solely in her capacity as the MCE Board representative for Napa County. 7 Created by Resolution No. 2026-01.

July 16, 2026
TO: MCE Board of Directors
FROM: Joy Massey, Manager of Transportation Electrification RE: MCE Application to the California Energy Commission’s GFO-25-608 - Electric Vehicle Hub, Outreach, Messaging, and Equipment (Agenda Item #05 C.4)
Dear Board Members:

Summary:

The California Energy Commission’s (CEC) GFO-25-608 - Electric Vehicle Hub, Outreach, Messaging, and Equipment (EV HOME) seeks to grant up to $5,000,000 for electric vehicle education, outreach, and charger installations to occur between from 2027-2030 in Disadvantaged (DAC) and Low-Income Communities (LIC). There is no match requirement for this grant and awardees are eligible to pursue an additional $5,000,000 in Phase II. Applications are due on August 18.

Staff reviewed the solicitation materials and deemed it to be a strong compliment to MCE’s existing electric vehicle programs. However, MCE’s EV programs and incentives are budgeted on a year-by-year basis whereas this grant would commit MCE to a three-year marketing effort to expand EV outreach and installation. The solicitation states the following:
“By providing the authorizations and certifications required under this solicitation, each Applicant agrees to enter into an agreement, if awarded, with the CEC to conduct the proposed project according to the terms and conditions that correspond to its organization, without negotiation: (1) University of California and California State University terms and conditions; (2) U.S. Department of Energy terms and conditions; or (3) standard terms and conditions.”
As a result, staff seeks Board authorization to submit an application to this three-year grant opportunity. If MCE’s EV programs are funded during this period, staff is strongly confident in our ability to meet the minimum grant requirements. If MCE’s EV programs are not funded in future years, the process for reaching these targets will require creative adaptation but is still possible.

Proposal
Staff propose to develop a $5,000,000 application to GFO-25-608 to fund education and outreach to support EV adoption, increase residential EV charging access, and expand managed charging benefits in low-income and disadvantaged communities. In partnership with Veloz, a Sacramento-based non-profit accelerating zero-emission vehicle adoption, and other local nonprofits, this grant would generate customized materials, host community education workshops, and facilitate warm leads. It would connect interested residents to relevant incentives, provide EV charging technical assistance, and subsidize a portion of EV charging equipment for single-family and multi-family residences. Subsidies vary by type and location, ranging from $1,000 per port to $6,000 per port.

Veloz is a national nonprofit focused specifically on accelerating EV adoption through large-scale education campaigns designed to make EV adoption simple, credible, and actionable for customers. Through this grant partnership, Veloz would provide MCE access to a ready-made library of regional digital media and messaging assets, stretching grant dollars further toward targeted outreach in low-income and disadvantaged communities.

Over the three-year grant term, this project will track the new acquisition of at least 250 electric vehicles and charging ports, as required by the grant. The project will also provide outreach and education to residents in low-income and disadvantaged communities and support the installation of EV charging infrastructure at single-family and multifamily properties through technical assistance and grant-funded incentives.

Alignment
This grant proposal is aligned with several existing MCE initiatives. If awarded, it would support the following efforts:
- MCE’s EV Instant Rebate Program
o Support MCE’s goals to increase EV education, adoption, charging equipment, and enrollment in managed charging
o While the grant does not fund vehicle incentives or rebates, project activities will bolster outreach to increase MCE’s program accessibility as well as interest in various local and state incentives and rebates
- MCE’s EV Charging Program
o Provide increased additional funding for technical assistance and incentives to support installation and purchase of EV chargers at multifamily housing and residential properties
o Strengthen MCE’s list of qualified installers, since the grant requires an Electric Vehicle Infrastructure Training Program (EVITP) certified electrician to be employed o Bolster outreach to increase interest in EV charging rebates for multifamily housing - MCE’s MCE Sync
o Support MCE’s goals to enable more EV households to benefit from VGI (Vehicle to Grid Integration) functionality
o Expand incentives to reduce costs of home charging and total cost of EV ownership o Provide additional funding to support incentives for residential at-home charging - MCE’s Virtual Power Plant
o Increase education around dispatchable distributed energy resources o Increase potential to enroll new distributed energy resources into the VPP - including bidirectional chargers
o New targeted outreach to create warm leads for new VPP participants Timing and Financial Considerations:

Applications are due August 18, 2026. Awards are anticipated to be selected by late October 2026.

If awarded, MCE would be given contract documents in March 2027, aligning with MCE’s Fiscal Year.

Because this grant is designed to significantly expand outreach and education, staff anticipate increased customer demand for MCE’s existing EV Instant Rebate and EV Charging Program incentives beginning in Fiscal Year Ending 2028. At that time, staff would need to forecast for the demand generated by these outreach activities.

Fiscal Impacts:

If selected, MCE and the grant partners would be awarded $5,000,000 to fulfill the above scope within 3 years. Successful completion of that award would facilitate MCE applying for a subsequent $5,000,000 in Phase II.

Recommendation:

Authorize staff to apply to the CEC’s GFO-25-608 grant opportunity, requesting up to $5,000,000 to fund EV education, outreach, and charger installation in Disadvantaged and Low-Income Communities.

July 16, 2026
TO: MCE Board of Directors
FROM: Maíra Strauss, Chief Financial Officer
RE: Proposed Exception to Operating Reserve Fund Policy Cap and Transfer (Agenda Item #05 C.5)
ATTACHMENT: Policy 016: Operating Reserve Fund
Dear MCE Board Members:

Summary:

Staff recommend deferring $80 million from the fiscal year ended 2026 (FYE 2026) revenues to the Operating Reserve Fund (ORF) to preserve financial flexibility and support future rate stability. Due to the timing of the planned $62 million withdrawal and current policy cap, the proposed transfer would exceed the cap, requiring a one-time waiver. As such, Staff also recommend a one-time exception to accommodate the transfer. MCE’s fiscal year runs from April 1 to March 31. On June 25 and July 6, 2026, MCE’s Finance Committee and Executive Committee, respectively, voted unanimously to recommend Board approval of both recommendations.

Background:

In November 2019, your Board approved Resolution 2019-06 establishing the ORF. The policy allows MCE to defer revenue pursuant Government Accounting Standard Board, Standard 62. MCE can defer revenue in strong financial years and recognize it in future years when financial performance is weaker or when needed to meet financial requirements. All transfers to and from the ORF require Board approval.

Since its establishment, your Board has approved four transfers totaling $70 million into the ORF.

The adopted FYE 2027 budget assumes a $62 million withdrawal, resulting in a projected ending balance of $8 million. This planned use of the ORF supports the 14% rate reduction implemented on April 1, 2026, and the temporary rate credit through December 2026, while avoiding a negative change in net position.Proposed Transfer to the ORF:

Interim (unaudited) financial results for FYE 2026 show total revenues1 of $803.5 million and a change in net position of about $82.2 million. These results provide capacity to defer additional revenue, and Staff recommend deferring $80 million to the ORF. 1 Total Revenues = Operating revenues + nonoperating revenues Due to the timing of the planned $62 million withdrawal in FYE 2027, the ORF balance would temporarily increase to approximately $150 million before declining. This amount exceeds the policy cap, which limits the ORF balance to 10% of total revenues. Based on FYE 2026 revenues, the cap is approximately $80.4 million. Staff expect the ORF balance to decline to a level closer to the cap by the end of FYE 2027 following the planned withdrawal. The chart below illustrates this timing difference.

Relative to peer CCAs, a temporary ORF balance of $150 million would be on the higher end, but not the highest among those with an ORF as shown below. Numbers shown are based on FYE 2025 audited financial statements. The proposed transfer is represented by the dotted border on MCE’s bar.
$70
$150
$88
9%
19%
11%
0%
3%
6%
9%
12%
15%
18%
21%
$0
$40
$80
$120
$160
FYE 2027 Start Temporary Balance FYE 2027 Expected
Million
ORF Balance
Balance ($M) % of FYE 2026 Total Revenues
$188
$138 $135 $128
$100
$70
$30
$0
$50
$100
$150
$200
Ava
Community
Energy
Sonoma
Clean
Power
Clean
Power
Alliance
Peninsula
Clean
Energy
Silicon
Valley
Clean
Energy
MCE Orange
County
Power
Authority
Millions
ORF Balances
Audited FYE 2025
Balance Proposed Transfer
Fiscal Impacts:

Deferring $80 million to the ORF would reduce the FYE 2026 change in net position by a like amount, causing the financial statements to show a change in net position of approximately $2.2 million. The ORF balance would temporarily increase to $150 million. The Board is welcome to recommend the use of remaining funds from the net position change from FYE 2026 to augment any Customer Programs (i.e. Heat Pump Water heaters) through a budget amendment later this year.

Recommendation:

Recommend that the Board of Directors approve both a temporary waiver of the ORF policy cap and an $80 million deferral of FYE 2026 revenues to the ORF.

POLICY 016: Operating Reserve Fund
Policy Purpose
The Operating Reserve Fund Policy will describe the situations in which staff will propose and the MCE Board of Directors will consider deposits into and withdrawals from the Operating Reserve Fund and establishes an Operating Reserve Fund Targeted Balance.

Policy Statement
The financial strength of MCE is one of the necessary pillars of the Agency if it is to deliver on its mission to address climate change by providing competitively priced renewable and GHG free energy to its customers. MCE will adopt policies and procedures designed to strengthen its financial position to allow the Agency to achieve these environmental goals. The MCE Board of Directors will adopt budgets and establish and adjust rates as necessary each fiscal year to provide sufficient revenues to pay all operating expenses and all other financial obligations of the agency. While MCE strives to meet its Reserve Policy targets, rates will be set to provide an addition to MCE’s Net Position whenever possible. MCE will also take the necessary steps to achieve and maintain strong investment grade credit ratings to minimize interest costs and counterparty collateral posting requirements.

To this end, in November of 2019 the MCE Board of Directors approved Resolution 2019-06 creating an Operating Reserve Fund and later approved the first deferral of revenue into the Operating Reserve Fund effective the end of the 2019-20 Fiscal Year. The Operating Reserve Fund has been established and will be maintained and utilized to strengthen MCE’s financial position and to be a tool to assist in addressing variability in MCE’s annual cashflows and expenses. The Operating Reserve Fund is not to be used to address specific expenses of the Agency, but rather as a tool that supports MCE’s ability to meet its financial obligations each fiscal year.

To the extent there is any conflict with Resolution 2019-06 which authorized the creation of the Operating Reserve Fund and this Policy 016, which provides directives for deposits to and withdrawals from the Operating Reserve Fund, this Policy 016, and any amendments thereto, shall control once approved by the MCE Board of Directors.

Policy Directives
Deposits: Staff will recommend and the Board will consider deferral of revenue into the Operating Reserve Fund in a fiscal year (1) when the projected addition to Net Position is greater than 5% of total operating and non-operating revenues or (2) once the Reserve Policy targets are met, from any excess net revenues after payment of any debt service or other financial obligations due in that fiscal year Operating Reserve Fund Targeted Balance: Deposits can be made into the Operating Reserve Fund as allowed above until the balance equals 10% of the total operating and non-operating Revenues in the then current fiscal year.

Withdrawals: Staff will recommend withdrawals of Revenues from the Operating Reserve Fund in a fiscal year where net revenues are projected to be negative or as necessary to satisfy any legal covenants, contractual obligations or to maintain investment grade credit ratings. 1 -
July 16, 2026
TO: MCE Board of Directors
FROM: Sabrinna Soldavini, Vice President of Policy
Johnstone Kipyator, Principal Manager, Power Analytics
Sai Powar, Policy Analyst
RE: Integrated Resource Plan (Agenda Item #06)
ATTACHMENTS: A. Presentation – Integrated Resource Plan Proceeding B. MCE 2026 IRP Narrative
C. MCE 2026 IRP Resource Data Template
D. MCE 2026 IRP Clean System Power Template
E. Key Acronyms
Dear Board Members:

Summary:

In accordance with the Board’s authority granted in Public Utilities Code (Code) Sections 366.2(a)(5) and 454.52(b)(3), Staff presents its proposed 2026 Integrated Resource Plan (IRP), including its Preferred Conforming Portfolio (PCP), for consideration and approval prior to submission to the California Public Utilities Commission (CPUC) on August 10, 2026.

Staff recommends the Board:

1. Approve MCE’s 2026 IRP and Preferred Conforming Portfolio (PCP); and

2. Direct Staff to finalize and file MCE’s 2026 IRP in substantially the same form and substance as approved, including any supporting pleadings and motions on August 10, 2026, and submit any supplemental materials as may be required.

Background:

Code Section 454.52 requires all CPUC jurisdictional load serving entities (LSEs), including Community Choice Aggregators (CCAs) such as MCE, to file an IRP with the CPUC every two years.1

The IRP encompasses a long-term planning horizon and details the procurement plan each LSE has adopted to meet the state’s goals of reducing greenhouse gas (GHG) emissions and maintaining reliability.
1 While LSEs are generally required to submit an IRP every two years, the CPUC delayed the 2024 IRP LSE submission cycle to 2026.
2 To reinforce the procurement autonomy of CCAs, Section 454.52(b)(3) requires that the IRP of a CCA be submitted to its governing board for approval and requires that the IRP meet the following:
(A) Economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals of achieving 40% reduction in GHG emissions from 1990 levels by 2030 and procure 50% renewable energy resources by December 31, 2030.
(B) A diversified procurement portfolio consisting of both short-term and long-term electricity and electricity-related and demand reduction products. (C) Resource Adequacy requirements.

Introduction
The IRP proceeding is an “umbrella” procurement planning process overseen by the CPUC that considers all of the CPUC’s policies and programs to ensure the state has a safe, reliable, and cost-effective electric supply”. 2 This is an iterative process with two tracks:

1. Planning: CPUC staff model and build a Preferred System Plan (PSP) for the state’s overall resource portfolio on a forward-looking basis. The PSP is based on load forecasts developed by the California Energy Commission (CEC), policy goals for renewable procurement and reliability, and GHG reduction targets. The PSP is a modeling scenario and represents the CPUC’s assumptions for an optimal resource portfolio that achieves the GHG benchmarks at least cost, while maintaining reliability. The CPUC allocates a portion of the PSP to individual LSEs like MCE, proportional to their load. Each LSE then submits a PCP as part of their individual IRPs to meet state targets and align with the PSP. PCPs submitted in an IRP year inform the next iteration of a 2-year process.
o IRP development is one step of a long-term, multi-year, iterative, and interconnected statewide planning process that spans multiple state agencies and LSEs. Most importantly, the PSP informs the California Independent System Operator’s (CAISO) Transmission Planning Process (TPP).

2. Procurement: The CPUC aggregates individual LSEs’ IRPs and measures the state’s progress on reliability and renewable procurement. Based on its evaluation, the CPUC determines the need for additional procurement to fill identified shortfalls which can (and has) led to mandatory procurement orders.
2024-2026 IRP cycle3
Based on portfolio planning information submitted by LSEs in the 2022 IRP process, the CPUC developed a 2023 PSP that informs the 2026 IRP process. For the 2024-2026 IRP cycle, the modeling 2 https://www.cpuc.ca.gov/irp/
3 2024-2026 IRP Cycle Events and Materials. https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/long-term-procurement-planning/2024-26-irp-cycle-events-and-materials. 3 years include 2026, 2028, 2030, 2035, 2040, and 2045, with GHG emissions limits of 25 million metric ton (MMT) in 2035 and 8 MMT by 2045. A few important aspects of the Commission's PSP analysis and results include:
4 • 70 percent of the selected builds are solar and battery storage; • Nearly the full potential of conventional geothermal, onshore wind, and location-constrained storage is built;
• A small amount of Enhanced Geothermal Systems (EGS) resources is built in 2045; • The GHG emissions target is binding for all model years; and • Use of natural gas declines to meet the GHG target, but natural gas capacity is retained for reliability events through 2045.

MCE’s 2026 IRP
MCE is required to complete and file three templates for the 2026 IRP filing by August 10, 2026:

1. Resource Data Template (RDT) – A CPUC tool used to report MCE’s existing energy and capacity contracts and to build a PCP of planned, new long-term contracts to meet MCE’s load, reliability, and emissions targets for all planning years. The RDT allows for an assessment of the portfolio’s level of reliability over the planning horizon (2026-2045);

2. Clean System Power (CSP) tool – A CPUC tool used to estimate and demonstrate the GHG and criteria pollutant emissions of MCE’s PCP; and

3. Narrative report – Outline MCE’s analysis, results, and provide a description of MCE’s planning and programmatic efforts for the future.

MCE’s assigned GHG benchmarks for the 2026 IRP are provided in Table 1 below. 2030 2035 2040 2045
Load
(GWh) 6362 7600 8508 8980
GHG Benchmark
(MMT) 0.513 0.393 0.332 0.170
Table 1: MCE's assigned GHG benchmarks for the 2026 IRP Guiding Principles for MCE’s 2026 IRP:

As part of its planning and design process for the PCP, MCE considers the following Guiding Principles. This list is not in any order of priority, and the principles are not mutually exclusive of each other:
4 2026 CPUC Filing Requirements Modeling. https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2024-2026-irp-cycle-events-and-materials/2026-cpuc-filing-requirements-modeling.pptx 4 • Mission & Board Policy: Meet Board-approved renewable procurement and emissions targets and comply with all Board-adopted procurement directives; • Regulatory Compliance: Comply with CPUC procurement-related rules and regulations, including procurement orders and resource adequacy (RA); • Affordability: Build a portfolio that ensures stable and affordable rates for MCE customers; • Risk Management: Incorporate contract terms and lengths and procurement timelines to minimize market risk impacts on MCE customers;
• Technology Diversity: Invest in a diverse portfolio of clean technology types; and • Clean Reliability: Progress towards a cleaner RA portfolio.

Modeling Approach for MCE’s 2026 IRP
MCE developed its IRP through the steps outlined below. Developing the IRP was an iterative process during which MCE staff balanced Board policies, regulatory requirements, and market realities related to resource availability and pricing to remain in alignment with the Guiding Principles mentioned above.

1. MCE compiled data for its existing energy-only contracts, bundled energy and capacity contracts, RA capacity contracts, and its share of capacity for allocated Cost Allocation Mechanism (CAM) and Demand Response resources and energy from hydro-electric and nuclear allocations;

2. For each IRP planning year, MCE identified its short positions relative to MCE's planning targets and assigned load forecast and populated the RDT with all current contracts;

3. MCE identified future contracts it expects for new geothermal, storage, and wind generation and prioritized the selection of future resources to ensure that MCE’s overall portfolio of new resources is in alignment with the Guiding Principles mentioned above.

4. MCE used the Commission’s CSP calculator to check the GHG emissions associated with the resulting portfolio to confirm that these emissions are lower than MCE’s assigned emissions benchmark;

5. MCE also performed a sensitivity analysis to understand the impacts of increasing the procurement of clean RA resources (explained below).

6. MCE identified the resulting portfolio as its Preferred Conforming Portfolio or PCP.

A key consideration during this process was the Commission’s methodology to determine Net Qualifying Capacity (NQC) for resources using the Effective Load Carrying Capacity (ELCC) methodology. Under this methodology, the nameplate capacity of a specific resource is discounted by a technology specific ELCC factor; this results in in the NQC, which is one way of determining an intermittent resource’s contribution towards meeting load on the grid. 5 The NQC of a resource is the
5 For example, consider a battery storage resource with a nameplate capacity of 100 MW. In 2026, the ELCC for battery storage resources is 90% so 90 MW of NQC is counted towards reliability requirements. In 2045, the ELCC for battery storage resources is 20%, meaning that 20 MW of NQC of the same 100 MW resource is counted towards reliability requirements.
5 value that counts towards final reliability procurement requirements. Because ELCC factors for solar and battery resources decline significantly in outer years of the planning period, MCE’s PCP includes a significant buildout of new resources to account for reducing NQC.

MCE’s 2026 IRP PCP
MCE developed its PCP consistent with the renewable energy and GHG-free goals summarized in Table 2 below.6

Portfolio
Targets (%) 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 PCC 1
Renewable
(Light
Green)
60% 65% 70% 75% 80% 85% 85% 85% 85% 85%
Carbon-free 37% 32% 27% 22% 17% 12% 12% 12% 12% 12%
GHG Free 95% 95% 95% 95% 95% 95% 95% 95% 95% 95%
Table 2: MCE's Internally Adopted Renewable and GHG-free Energy Targets MCE’s PCP includes plans for significant capacity additions of new renewable and storage resources by 2045 to support achievement of MCE’s renewable and GHG-free energy goals, while contributing to system reliability in a responsible manner.

MCE’s PCP includes the following planned new nameplate capacity over the planning period:
• In-state and out-of-state wind resources totaling 801 Megawatts (MW) • Geothermal resources totaling 96 MW;
• Solar resources totaling 1,624 MW (imported and California solar); • 4-hour battery storage resource totaling 803.5 MW; and • 8-hour battery storage resource totaling 1,201.7 MW.

MCE’s PCP provides for the following overall energy resource mix in 2045:
• Wind (in-state and out-of-state) of 2,322 GWh
• Geothermal of 1,617 GWh;
• Hydro-electric (large) of 500 Gigawatt Hours (GWh);
• Solar (California) of 4,446 GWh; and
• Standalone battery storage of -538 GWh net (Capacity x duration)7 .
6 These targets were incorporated into MCE’s 2026 budget process and were approved with the Fiscal Year 2026/2027 Budget. These targets will be incorporated into future planning efforts such as the IRP and MCE’s Renewables Portfolio Standard (RPS) Procurement Plan until modified by the Board in the future. 7 Batteries are net energy consumers because of the energy required to charge these resources. In 2045, MCE’s PCP includes battery resources with 10,640 MWh of dispatch capability and -538 GWh corresponds to the overall additional energy needed to charge those resources (round trip efficiency losses). The fleet of 6 New Resource Additions in PCP
MCE’s PCP includes a mix of existing and new resources strategically integrated to adhere to MCE’s policy to achieve at least 85% renewable energy by 2031 and continue to reduce emissions through 2045 to meet state targets.

Through its currently contracted long-term capacity and planned contracts in the PCP, MCE plans to:
• Procure approximately 92% of its renewable energy from long-term contracts by 2045; • Contract for more than 46 MW of new build renewable energy capacity within MCE’s service area;
• Contract for more than 2,928 MW of new build renewable energy capacity throughout California;
• Contract for 2,628 MW of storage capacity to help shift peak demand and support grid reliability, benefiting hourly accounting and energy costs; and • Bring online over 860 MW of nameplate capacity from renewable resources in the next six years to serve reliability needs.

Of note, and as depicted in Figure 1 below, new resources comprise approximately 4,000 MW of MCE’s PCP, reflecting MCE’s active role in the State’s development of new storage and renewables.

Figure 1: Cumulative New Resource Additions by Resource Type in PCP The above results are intended for illustrative incremental portfolio analysis only. Actual procurement choices would differ and follow Board-approved procurement practices. batteries charge to 3,581GWh but only discharge 3,043GWh, losing 538GWh annually. 472GWh is attributed to the 8hr batteries and 66GWh from 4hr batteries.
7 Contract Lengths in PCP
Given that the IRP process is intended for long-term planning, all of MCE’s new resource additions in MCE’s PCP are long-term contracts (typically 10 or 20-year terms). MCE’s current long-term contracts account for 48% of projected sales in 2026 and up to 67% by 2030.

MCE currently utilizes short-term contracts as needed to meet its customer load, internal RPS targets, internal clean energy targets, RA requirements, and load hedging needs. To the extent MCE’s Board directs changes to MCE’s procurement strategy, those changes will be reflected in future MCE filings.

Emissions Results of PCP
MCE’s forecasted GHG emissions based on the PCP, as well as MCE’s GHG assigned 2035 and 2045 load forecast and corresponding GHG emissions benchmarks, are estimated using the CPUC’s CSP calculator and shown in the table below. Inclusion of natural gas Resource Adequacy capacity in MCE’s PCP does not compromise MCE’s progress towards emissions reductions, as incremental additions of new, clean resources will translate to lower utilization of natural gas plants towards system power.
2030 2035 2040 2045
Load (GWh) 6362 7601 8508 8980
GHG Benchmark
(MMT) 0.513 0.393 0.332 0.170
PCP Annual
Emissions (MMT) 0.35 0.27 0.20 0.14
Table 3: Emissions Results of PCP
RA Resources in MCE’s PCP
MCE is committed to maintaining reliability for its customers and aligning with the state’s reliability goals and planning scenarios. MCE’s short- and long- duration storage, renewable baseload procurement, and its RA capacity-only resources will help maintain MCE’s critical role in supporting the State’s need for reliability and renewable integration.

CPUC modeling in the current IRP cycle demonstrates the State’s need for natural gas resources through the planning period (2045) to ensure a reliable statewide grid.8 While MCE does not enter 8 CPUC 2026 IRP Modeling Results. https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/energy-division/documents/integrated-resource-plan-and-long-term-procurement-plan-irp-ltpp/2024-2026-irp-cycle-events-and-materials/2026-cpuc-filing-requirements-modeling.pptx. 8 into contracts to buy energy directly from natural gas generators, MCE’s portfolio does require natural gas for capacity purposes to reliably, feasibly, and affordably meet MCE’s RA requirements. 9 The proportion of natural gas relative to MCE’s total capacity portfolio is summarized in Table 4 below.

Modeling
Year
Natural Gas Capacity (%)
NQC Nameplate
2026 75% 44%
2030 57% 24%
2035 48% 17%
2040 37% 13%
2045 41% 16%
Table 4:Summary of natural gas in MCE's capacity portfolio 9 https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/resource-adequacy-homepage.

A portion of the thermal (natural gas) capacity in MCE’s portfolio comes from the CPUC’s Cost Allocation Mechanism (CAM). CAM allows investor-owned utilities to procure resources for reliability purposes and allocate the costs and capacity value to all LSEs.
9 Figure 2: Natural Gas Capacity in MCE's PCP (% of total portfolio capacity) Cost Impacts of PCP
Once adopted, MCE’s IRP will become the guiding framework for MCE’s future procurement, and MCE’s procurement must generally be consistent with the IRP. However, adoption of an IRP does not equate to Board approval to enter into contracts to “build” the resources selected in the IRP. Any future procurement decisions must and will follow the Board approval process.

As the IRP utilized a 20-year planning horizon, and IRPs are updated on a two-year cycle, MCE does not expect to procure exactly what is adopted in its 2026 IRP. Instead, the PCP is intended to represent one reasonable and feasible portfolio that MCE could build out to meet its share of the State’s reliability and GHG-emissions requirements and to help guide MCE and statewide procurement policy between now and the next IRP cycle. Accordingly, a primary goal of the IRP for MCE is to select a portfolio that accomplishes the aforementioned goals, but which also leads to affordable rates for MCE customers.

If MCE were to build and bring online all the resources included in the PCP (per the exact resource mix and planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information10 MCE expects the following affordability and ratepayer impacts:

1. MCE’s generation rate11 would increase annually by 5% on average. 10 Pricing information is derived from a combination of cost assumptions from the CPUC’s RESOLVE model and internal knowledge sourced from prior MCE solicitations. 11 Generation rate refers to the Residential E-TOU-C rate plan based on a weighted average rate of customer usage across seasons (summer/winter) and time-of-use (on-peak/off-peak) periods. 0%
20%
40%
60%
80%
100%
0%
20%
40%
60%
80%
100%
Total Natural Gas capacity (NQC) is inclusive of CAM* Allocation Natural Gas Capacity CAM Allocation
10 2. By 2045, MCE’s rates would cumulatively increase by 18.80 cents/kilowatt-hour (kWh), a 150% increase to the current generation rate.
11 The rate impacts described above and shown in Figure 2 below are intended for illustrative incremental portfolio and ratepayer impact analysis only. To balance rate impacts with the need to Critically, MCE does not have a Board-approved rate mechanism to directly pass through power procurement costs to customers via rate increases. .Any future rate changes would require Board approval, and actual net cost and rate impacts would depend on all costs and revenues.

Figure 3: Cost Impacts of MCE’s 2026 PCP
“Clean RA” Sensitivity Analysis
To understand and demonstrate the impacts of replacing natural gas capacity in MCE’s PCP with a greater percentage of clean RA resources, MCE performed a sensitivity analysis by creating an alternative conforming portfolio (Clean RA Scenario or Scenario) for consideration. The Clean RA scenario assumes MCE continues to meet all internal targets and CPUC requirements, but incrementally replaces a portion of natural gas RA capacity with clean RA resources over the planning period. The Clean RA Scenario reflected a reduction in natural gas capacity reliance in MCE’s IRP portfolio from 75% of the RA portfolio in 2026 to 25% in 2045. MCE presented the Clean RA scenario (Figure 3) to the Technical Committee on June 5, 2026. 11 Figure 4: Cumulative New Resource Additions by Resource Type in Alternative Conforming Portfolio Figure 5: Comparison of cumulative new resource additions between MCE's PCP and Clean RA alternative scenario As MCE adds new clean resources over the planning horizon, the proportion of natural gas within its RA portfolio in the PCP is projected to decrease (Table 4). The Clean RA Scenario demonstrates that MCE would need to contract for 5,106 MW of new clean resource capacity over the planning horizon; 579 MW more than MCE’s PCP as summarized in Table 5. 2035 2045
GHG Benchmark (MMT) 0.393 0.170
PCP Annual Emissions
(MMT)

0.27 0.14
12 Clean RA Alternative
Portfolio Emissions (MMT)

0.32 0.169
Table 4: Emissions Results of MCE’s 2026 PCP and Clean RA alternative portfolio Based on MCE’s experience and understanding of the market, Staff believe that procuring the amount of new clean resources in the Clean RA Scenario would be challenging, more costly, and result in over procurement relative to 2045 needs. As previously mentioned, MCE does not expect to procure the exact set of resources included in the PCP. However, the CPUC uses LSE IRPs to plan statewide procurement and MCE endeavors to submit a portfolio that can feasibly and reasonably procure to ensure MCE is not providing inaccurate signals.

For example, as shown in Table 5 below, under the Clean RA Scenario MCE would need to contract for approximately 299 MW more nameplate capacity of geothermal resources between 2026 and 2045 than the PCP. Currently, geothermal is an extremely scarce and expensive resource, and indicating that MCE could contract at the levels demonstrated in the Clean RA Scenario would be highly speculative at this time, and not representative of what Staff believe is reasonable to build.

Resource Type PCP (MW) Clean RA
Scenario
(MW)
Change
Battery Storage 2,005 2,398 +393
Geothermal 96 395 +299
Solar 1,624 1,412 -212
Wind 801 900 +99
Total 4,526 5,106 +579
Table 5: New Resource Additions in Alternative Conforming Portfolio, 2026 – 2045 Additionally, the Clean RA Scenario would likely result in significant rate increases for MCE customers. If MCE were to build and bring online all the resources included in the Clean RA Scenario (per the exact resource mix, amount, and planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information12 MCE expects the following affordability and ratepayer impacts:

1. MCE’s generation rate11 would increase annually by 6% on average.

2. By 2045, MCE’s rates would cumulatively increase by 24.34 cents/kilowatt-hour (kWh), a 194% increase to the current generation rate.
11 12 Pricing information is derived from a combination of cost assumptions from the CPUC’s RESOLVE model and internal knowledge sourced from prior MCE solicitations. 13 Although the 20-year impact appears modest, as shown in Figure 4, the 20-year timeframe suppresses the year-over-year cost impact on customers.

Figure 4: Cost impacts of Alternative Conforming Portfolio Staff plans to continue to invest in clean RA resources and progressively reduce reliance on natural gas for RA, while balancing across all other Guiding Principles. MCE’s Technical Committee generally expressed a preference to move forward with MCE’s current PCP in response to the projected cost increases of the alternative portfolio (Clean RA Sensitivity) and practicality of contracting with scarce resources, and to present alternative portfolio as a sensitivity analysis that was conducted.

Accordingly, Staff recommend that the Board approve MCE’s PCP for the purposes of this IRP submission. Going forward, Staff remain open to feedback on MCE’s procurement efforts towards procuring Clean RA resources.

As described above, the results of the Clean RA Scenario described in this section are intended only to illustrate incremental portfolio and rate impact analyses. Actual procurement choices will differ and follow Board-approved procurement practices. Any future rate changes would require Board approval, and actual net cost and rate impacts would depend on all costs and revenues.

Fiscal Impacts:

While the 2026 IRP serves as a guiding document for MCE’s procurement and demonstrates the resources and volumes MCE seeks to procure, there are no direct or immediate fiscal impacts of adopting MCE’s 2026 IRP. All future resource commitments made to implement the plan will be subject to separate approval in accordance with MCE’s adopted delegation of authorities. Staff will provide an annual update to its Board of Directors (or delegated subcommittee) on progress towards its 2026 IRP.

Recommendation:

Staff Recommends the Board:
14 1. Approve MCE’s 2026 IRP and Preferred Conforming Portfolio (PCP); and

Integrated Resource Plan
Board Meeting
July 16, 2026
What We Are Asking Today
2 Seeking Approval of MCE’s 2026 Integrated
Resource Plan (IRP), including its Preferred
Conforming Portfolio (PCP).
• Focus: IRP Approval and Planning Portfolio
• Today is NOT: Approval of specific projects, contracts, or budgets.

All future procurement decisions will still come to the Board for approval.

Background on the IRP
3 • All CPUC jurisdictional LSEs required to file an IRP every 2 years that details the LSE’s long-term procurement plan to meet State reliability goals and GHG emissions targets over the planning horizon
• Each CCA’s IRP needs to be submitted to its governing board for approval and requires that the IRP meet the following:
• “Economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals of achieving 40% reduction in GHG emissions from 1990 levels by 2030 and procuring 50% renewable energy resources by December 31, 2030.
• A diversified procurement portfolio consisting of both short- and long-term electricity and electricity-related and demand reduction products.
• Resource Adequacy requirements”.
2026 is an IRP year!
What is the IRP and How Does it Work?
4 IRP = Integrated Resource Plan
Key Goal: Identify a diverse
portfolio of resources to meet
grid reliability needs & support
CA’s Greenhouse Gas (GHG)
emissions reductions goals.

California Public Utilities
Commission (CPUC) oversees
the IRP and sets resource
planning targets for Load
Serving Entities (LSEs) within
its jurisdiction.

Iterative process with two tracks that impact
MCE procurement, budget, and ratepayers:

1. Planning
• The CPUC builds its Preferred System Plan
(PSP) portfolio based on load forecasts,
state policy goals, and statewide emissions
targets.
• LSEs prepare individual IRPs that are
aggregated and evaluated against the
PSP.
• This track also informs transmission
planning

2. Procurement
• CPUC evaluates and determines if there is a
need for additional procurement to fill
identified shortfalls.
• This can (and has) lead to mandatory
procurement orders.

How Does MCE Participate in the IRP?
5 MCE regularly engages in CPUC-related proceedings to advocate for reasonable load forecast and planning assumptions, as well as fair procurement obligations.

MCE submits an IRP to the CPUC every two years:
• After development of the PSP, the CPUC allocates a portion of the PSP to individual LSEs like MCE.
• MCE is required to develop and submit a Preferred Conforming Portfolio (PCP or Portfolio) over the 2026-2045 planning horizon. • MCE’s PCP outlines its procurement model demonstrating its ability and plan to meet MCE’s share of statewide reliability need and GHG targets. 2024 – 2026 IRP Cycle
6 • The 2026 IRP is based on the 2023 System Plan that the CPUC modelled based on planning information from the 2022 IRP process. • Modelling years included 2026, 2028, 2030, 2035, 2040, and 2045, with GHG emissions limits of 25 million metric ton (MMT) in 2035 and 8 MMT by 2045
• Key aspects of the CPUC's PSP modelling analysis and results include:
• 70% of the builds modeled are solar and battery storage; • Nearly the full potential of conventional geothermal, onshore wind, and location-constrained storage is built;
• Use of natural gas declines to meet the GHG target, but natural gas capacity is retained for reliability events through 2045 2026 IRP Requirements
7 • MCE’s IRP demonstrates how MCE will meet its share of the 25 Million Metric Tons (MMT) by 2035 and 8 MMT by 2045 GHG target.
• Submission Requirements:
• Resource Data Template (RDT) - Reports MCE’s existing energy and capacity contracts and builds a PCP of planned contracts to meet MCE’s load, reliability and emissions targets • Clean System Power (CSP) tool – Used to estimate and demonstrate the GHG and criteria pollutant emissions of MCE’s PCP
• Narrative report – Outlines MCE’s analysis, results, and provide a description of MCE’s planning efforts for the future
Draft IRP
Feedback
June
5 Seek Approval of
Final IRP July Final IRP
Submission
August
10 Impacts: What IRP Does and Does Not Do
8 The IRP does NOT
• Determine specific or exact cost impacts for
MCE.
• Select individual projects or contracts that
MCE must procure.
• MCE’s procurement authority resides
with this Board, and however the Board
delegates such authority.
• All future contracts for new resources
will continue to follow that approval
process.
• Align perfectly with market timing or
contract availability to ensure least cost,
optimal portfolios for individual LSEs.

The IRP does
• Directly impact MCE’s operation strategy
and budget.
• Influence and constrain (but does not
dictate) MCE’s future procurement
efforts.
• Impact on MCE’s procurement costs
through changes in market dynamics
and resource costs and availability.
• Have potential to result in procurement
mandates if the CPUC determines more
capacity is needed.

Guiding Principles for MCE’s PCP
9 Meet Board-approved renewable procurement and emissions targets and comply with all Board-adopted procurement directives
Mission & Board Policy
Comply with CPUC procurement-related rules and regulations, including procurement orders and resource adequacy (RA)
Regulatory Compliance
Build a portfolio that ensures stable and affordable rates for MCE customers
Affordability
Diversify contract types and lengths to minimize market risk impacts on MCE customers
Risk Management
Build a diverse portfolio of clean technology types
Technology Diversity
Continue to invest in clean RA resources
Clean Reliability
Portfolio Design: Modeling Approach
10 1. Compile data for existing contracts (energy-only, bundled energy and capacity, RA, Demand Response, allocations)

2. Identify short positions relative to planning targets and assigned load forecast

3. Design portfolio with new long-term contracts to meet load, emissions and reliability targets in modelling years
Key Considerations
• Net Qualifying Capacity (NQC) using the CPUC’s Effective Load Carrying Capacity (ELCC) Methodology
• Clean RA capacity and associated sensitivity analysis • Maintaining a balance between regulatory compliance & uncertainty and market realities
PCP: Assigned Load and Emissions Targets
11 2030 2035 2040 2045
Load
(GWh) 6362 7600 8508 8980
GHG
Benchmark
(MMT)

0.513 0.393 0.332 0.170
PCP meets all Board Approved Targets
12 Portfolio
Targets (%) 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 PCC 1
Renewable
(Light Green)
60% 65% 70% 75% 80% 85% 85% 85% 85% 85%
Carbon-free 37% 32% 27% 22% 17% 12% 12% 12% 12% 12%
GHG Free 95% 95% 95% 95% 95% 95% 95% 95% 95% 95%
PCP: New Planned Resource Additions
13 *Cumulative MW are nameplate capacity additions
These results are illustrative only. Actual procurement will differ and follow Board approved procurement processes.

New Planned Resource Additions in PCP
14 Resource type Contracted
Capacity (MW)
in 2026
Planned new
capacity* (MW)
Overall resource
mix (GWh) in 2045
Proportion of total
in 2045 [GWh](%)
Wind (in-state, out of
state) 305.2 801 2322 25%
Geothermal 137 96 1617 18%
Hydro-electric (large,
imported, small) 205.6 - 500 5%
Solar (California,
imported) 861.4 1624 4446 51%
Battery (4hr) 476.6 803.5
-538**
-
Battery (8hr) 35 1201.7 -
*Planned new capacity is nameplate capacity (Not NQC)
**Batteries are net energy consumers because of the energy required to charge these resources. In 2045, MCE’s PCP includes battery resources with 10,640 MWh of dispatch capability and -538 GWh corresponds to the overall additional energy needed to charge those resources. The fleet of batteries charge to a total of 3,581 GWh but only discharge 3,043 GWh, losing 538 GWh annually.

Emissions Results of PCP
15 2030 2035 2040 2045
Load
(GWh) 6362 7600 8508 8980
GHG
Benchmark
(MMT)

0.51 0.39 0.33 0.17
PCP Annual
Emissions
(MMT)

0.35 0.27 0.20 0.14
Contracts Lengths in PCP
16 • All of MCE’s new resource additions in MCE’s PCP are long-term contracts (typically 10 or 20-year terms).
• MCE’s current long-term contracts account for 48% of projected sales in 2026 and up to 67% by 2030.
• MCE currently utilizes short-term contracts as needed to meet its customer load, internal RPS targets, internal clean energy targets, RA requirements, and load hedging needs. To the extent MCE’s Board directs changes to MCE’s procurement strategy, those changes will be reflected in future MCE filings.

What MCE Has Built Through Long-Term
Contracts + IRP PCP
~92%
of MCE renewable
energy from long-term
contracts (2045)*
46+ MW
of new renewables built
directly in MCE's service
area
2,928 MW
of new
renewables statewide to
serve MCE customers
2,911 MW
of renewable energy
including draft IRP
portfolio since 2021
Energy Storage: 2,628 MW of storage including draft IRP portfolio — shifting renewable energy to hours of peak demand and adding grid reliability. A benefit for hourly accounting & energy cost.

MCE also offers a Feed-in Tariff program providing direct incentives for new clean energy projects within our service area — supporting hyperlocal renewable development. *2045 results will depend on load and portfolio optimization. 17 RA Resources in PCP
18 • MCE does not directly procure natural gas as
part of its energy supply for customers.

However, MCE sources Resource Adequacy
(capacity) from existing natural gas facilities.
• Natural Gas in MCE’s PCP: MCE will have
natural gas in its RA portfolio all the way
through 2045.
• CPUC’s PSP includes reliance on natural
gas to maintain reliability and MCE’s PCP
aligns with that planning direction.
• As MCE’s load is projected to increase, the
proportion of natural gas relative to entire
RA portfolio decreases.

Modelling
Year
Natural Gas Capacity
(%)
NQC Nameplate
2026 75% 44%
2030 57% 24%
2035 48% 17%
2040 37% 13%
2045 41% 16%
Natural Gas Capacity in PCP
19 0%
20%
40%
60%
80%
100%
0%
20%
40%
60%
80%
100%
2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 Total Natural Gas capacity (NQC) is inclusive of CAM* Allocation Natural Gas Capacity CAM Allocation
*The Cost Allocation Mechanism (CAM) implemented by the CPUC allows investor-owned utilities to procure resources for reliability purposes and allocate the costs and capacity value to all LSEs.

PCP: Affordability & Cost Impacts
20 If MCE built this exact portfolio, all else equal, based on current cost assumptions MCE’s generation rate would increase 150% by 2045.
**All future rate changes would require board approval and actual net cost and rate impacts would be dependent on all costs and revenues.
4%
11%
5%
6% 6% 6%
13%
5%
4% 4%
7%
7%
3% 3%
5%
2%
4%
-0.50

0.00 0.50

1.00 1.50

2.00 2.50

3.00 -5
0 5
10 15
20 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 Change in ¢/KWh
¢/KWh
Preferred Conforming Portfolio Rate Impacts (Nominal ¢/KWh) Annual Rate Impact Cummulative rate impact
Clean RA Sensitivity Analysis
21 • Staff performed a Clean RA
sensitivity (“Clean RA Scenario”)
analysis to demonstrate the
impacts of replacing natural gas
capacity in MCE’s PCP with clean
RA resources and created an
alternative portfolio
• Scenario analyzed: Natural gas
capacity decreases from 75% in
2026 to 25% in 2045
New Resource Additions (Nameplate capacity)
Resource Type PCP
(MW)
Clean RA
Scenario
(MW)
Change
Battery Storage 2,005 2,398 +393
Geothermal 96 395 +299
Solar 1,624 1,412 -212
Wind 801 900 +99
Total 4,526 5,106 +579
Clean RA Scenario
22 These results are illustrative only. Actual procurement will differ and follow Board approved procurement processes.

Clean RA Scenario
23 These results are illustrative only. Actual procurement will differ and follow Board approved procurement processes.

Clean RA Scenario: Affordability & Cost Impacts
24 If MCE built this exact portfolio, all else equal, based on current cost assumptions MCE’s generation rate would increase 194% by 2045.
*All future rate changes would require board approval and actual net cost and rate impacts would be dependent on all costs and revenues.
4%
12%
8%
15%
8%
6%
15%
5%
3% 4%
5%
12%
2% 2%
6%
2%
5%
-0.50

0.00 0.50

1.00 1.50

2.00 2.50

3.00 3.50

4.00 -5
0 5
10 15
20 25
30 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 Change in ¢/KWh
¢/KWh
Clean RA Alternative Portfolio - Rate Impacts (Nominal ¢/KWh) Annual Rate Impact Alternate Cummulative Rate Impact Alternate Affordability & Cost Impacts Comparison
25 *All future rate changes would require board approval and be dependent on many factors. 0 5
10 15
20 25
30 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 ¢/KWh
Portfolio Rate Impacts Comparison (% Change)
Cummulative rate impact Alternate Cummulative rate impact PCP Clean RA Scenario
PCP
Clean RA Sensitivity Analysis
26 • Staff expect that the scarcity of geothermal and wind resources will make them difficult to procure and costly for MCE’s customers.
• Staff presented the current PCP and Clean RA Scenario to the Technical Committee. The Technical Committee:
• Expressed a preference to move forward with MCE’s current PCP in response to the projected cost increases of the alternative portfolio (Clean RA Sensitivity) and practicality of contracting with scarce resources • Recommended presenting the sensitivity analysis for awareness Looking Ahead: MCE will continue investing in clean RA resources while also balancing across all other Guiding Principles. MCE is committed to continuous discussion on its clean RA efforts.

Recommendation for MCE’s 2026 IRP
27 Staff Recommends the Board:

1. Approve MCE’s 2026 IRP, including its PCP; and

2. Direct Staff to finalize and file MCE’s 2026 IRP
in substantially the same form and substance as
approved, including any supporting pleadings, motions,
and supplemental materials as may be needed, to the
CPUC on August 10, 2026.

Thank you!
mceCleanEnergy.org
[email protected]
Attachment B
MCE 2026 IRP Narrative
Public Version

Standard LSE Plan
Marin Clean Energy
2026 INTEGRATED RESOURCE PLAN
August 10, 2026

1 Table of Contents
I. Executive Summary ............................................................................................................... 4 a) Introduction ................................................................................................................. 4 b) Summary of Findings .................................................................................................... 7 II. Study Design ........................................................................................................................10 a) Objectives ...................................................................................................................10 b) Methodology ..............................................................................................................10 i. Modeling Tool(s).....................................................................................................................10 ii. Modeling Approach ................................................................................................................11 iii. Alternative Assumptions.........................................................................................................14 III. Study Results .......................................................................................................................15 a) Conforming Portfolio ..................................................................................................15 b) Preferred Conforming Portfolio .................................................................................25 c) GHG Emissions Results ...............................................................................................33 d) Local Air Pollutant Minimization and Disadvantaged Communities ..........................33 i. Local Air Pollutants.................................................................................................................33 ii. Focus on Disadvantaged Communities...................................................................................34 e) Cost and Rate Analysis ...............................................................................................41 f) System Reliability Analysis .........................................................................................44 g) Hydro Generation Risk Management .........................................................................46 h) Long-Duration Storage Planning ................................................................................47 i) Clean Firm Power Planning ........................................................................................47 j) Non-CAISO, including Out-of-State, Wind Planning ...................................................48 k) Offshore Wind Planning .............................................................................................49 l) Transmission Planning ................................................................................................49 IV. Action Plan ...........................................................................................................................52 m) Proposed Procurement Activities and Potential Barriers ...........................................52 i. Resources to meet IRP mandated procurement requirements, including D.21-06-035 and D.23-02-040 ......................................................................................................................................55 ii. Plans for resources that are currently non-candidate in CPUC’s IRPs not described above ..59 2 iii. Other renewable energy not described above.......................................................................60 iv. Other energy storage not described above............................................................................60 v. Other demand response not described above .......................................................................60 vi. Other energy efficiency not described above.........................................................................60 vii. Other distributed generation not described above................................................................66 viii. Transportation electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR).........................................................................................67 ix. Building electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR).............................................................................................68 x. Potential Centralized Procurement, pursuant to AB-1373.....................................................71 n) Disadvantaged Communities .....................................................................................71 o) LSEs’ Tribal Customers ...............................................................................................75 p) Procurement Products ...............................................................................................75 q) Commission Direction of Actions ...............................................................................75 V. Lessons Learned ..................................................................................................................76 VI. Glossary of Terms ................................................................................................................76

3 List of Tables
Table 1: MCE’s 2023-2045 Assigned Load Forecast .....................................................................12 Table 2: Summary of MCE's PCP ..................................................................................................16 Table 3: Summary of MCE's Share of TPP Resources ...................................................................16 Table 4: MCE's 2045 PCP Resources .............................................................................................25 Table 5: Emissions Results for MCE's PCP ....................................................................................26 Table 6: Comparison of 8 MMT by 2045 PCP and 25 MMT by 2035 PCP from MCE's 2022 IRP ..32 Table 7: MCE's PCP GHG Emissions ..............................................................................................33 Table 8: MCE's PCP Local Pollutant Emissions .............................................................................33 Table 9: Summary of MCE contracted facilities within a DAC or within a 5-mile radius of a DAC34 Table 10: DACs Served by MCE ....................................................................................................37 Table 11: MCE's Reliability Need, Total Supply, and Net Capacity Position (2026 - 2045) ..........44 Table 12: MCE's Procurement Requirements ordered under MTR Procurement .......................56 Table 13: Summary of procurement products MCE intends to use .............................................75 List of Figures
Figure 1: Map of MCE's Service Area ............................................................................................. 4 Figure 2: Average portfolio cost over the planning period for MCE's PCP ...................................43 Figure 3: Rate Impact of MCE's PCP .............................................................................................44 Figure 4: MCE's Capacity by Contract Status (2026 - 2045) .........................................................45 Figure 5: Total System Benefit of MCE's EE portfolio (2026-2035)..............................................62 Figure 6: TRC ratio of MCE's EE portfolio (2026 - 2035)...............................................................62

4 I. Executive Summary
a) Introduction
Description of MCE
Marin Clean Energy (“MCE”) is California’s first Community Choice Aggregation (“CCA”) Program, a not-for-profit Joint Powers Authority (“JPA”) that began service in 2010. As a load-serving entity (“LSE”), MCE provides electricity generation service to approximately 600,000 customer accounts, representing more than 1.8 million residents and businesses across four Bay Area counties.1 MCE procures for annual retail sales of approximately 5,500 GWh and a peak load of more than 1,400 MW.

MCE provides service to approximately 87% of eligible customers within its service area, which is shown in Figure 1, below. MCE is the default generation provider for any new or relocated customers therein.2
Figure 1: Map of MCE's Service Area
1 MCE serves communities across Contra Costa, Marin, Napa, and Solano counties. Those communities currently receiving service include: Unincorporated Contra Costa, Marin, Napa, and Solano counties and the Cities and Towns of American Canyon, Belvedere, Benicia, Calistoga, Concord, Corte Madera, Danville, El Cerrito, Fairfax, Fairfield, Hercules, Lafayette, Larkspur, Martinez, Mill Valley, Moraga, Napa, Novato, Oakley, Pinole, Pittsburg, Pleasant Hill, Richmond, Ross, St. Helena, San Anselmo, San Pablo, San Rafael, San Ramon, Sausalito, Tiburon, Vallejo, Walnut Creek, and Yountville.
2 MCE expanded service to the city of Hercules in April 2025. This expansion is reflected in MCE’s Commission-assigned load forecast. Expansion to additional communities may occur during the planning period. 5 As a JPA and local government agency, MCE is governed by a 34-member Board of Directors (“Board” or “Governing Board”) composed of elected representatives from MCE’s member communities. MCE’s Board sets the agency’s policies and oversees its operations, including procurement planning. Through these representatives, MCE is controlled by and accountable to the communities MCE serves.

MCE’s Mission
MCE’s mission is to confront the climate crisis by eliminating fossil fuel greenhouse gas (“GHG”) emissions, producing renewable energy, and creating equitable community benefits. MCE’s vision is to lead California to an equitable, clean, affordable, and reliable energy economy by serving as a model for community-based renewable energy, energy efficiency, and cutting-edge clean-tech products and programs.

Consistent with Sections 366.2(a)(5) and 454.52 (b)(3), MCE’s procurement is governed by MCE’s Board and must be consistent with the Board-adopted policies. As a mission-driven local government agency, MCE works toward the following goals:
● Reducing GHG emissions through strategic programs and energy service options, maximizing both renewable and carbon-free sources;
● Fostering equity by focusing on inclusive participation and equitable access to clean energy, programs, and benefits; and
● Strengthening energy affordability by expanding access to cost-saving programs and advocating for fair rates to lower customer costs.

Introduction to MCE’s IRP
In accordance with the requirements of Sections 454.51 and 454.52, Commission Decisions (“D.”) 26-02-057, 23-02-040, 22-02-004, D.21-06-035, D.19-11-016, D.18-02-018, and formal guidance provided by the Commission’s Energy Division,
3 MCE is filing its Integrated Resource
Plan (IRP) for certification review and use in the Commission’s statewide planning process. In addition to this narrative, MCE’s IRP includes the following documents:
● MCE’s 8 MMT Resource Data Template; and
● MCE’s 8 MMT Clean System Power Calculator.

As provided for in D.24-02-047 and described in Commission Guidance documents, MCE is submitting a single conforming portfolio, the “Preferred Conforming Portfolio” (“PCP”), which meets its proportional share of the 8 MMT by 2045 emission limit. 3 2024-2027 IRP Cycle Events and Materials. https://www.cpuc.ca.gov/industries-and-topics/electrical-energy/electric-power-procurement/long-term-procurement-planning/2024-27-irp-cycle-events-and-materials. 6 Projecting resource needs over the planning horizon covered by the IRP is an inexact exercise and is appropriately subject to change in terms of both amounts and type of resources needed.

MCE’s PCP generally includes (a) existing and operating resources that are under contract with MCE; (b) resources that MCE has contracted for, but that have not achieved commercial operation; and (c) future resources that MCE will need to procure to meet CPUC procurement orders and current Board-adopted targets over the mid- and long-term.

The future resources identified in MCE’s PCP represent MCE’s good-faith projection of the resource mix it will procure over the IRP planning horizon based on currently available information. The resource mix that MCE identifies in future IRP iterations, and the resources MCE ultimately procures over the planning horizon, may differ from those included in MCE’s PCP as a result of several dynamic factors including the iterative nature of the IRP process, evolving market conditions, MCE Board policy, and state and federal policy changes. However, MCE remains committed to procuring a diverse resource mix that effectively balances affordability and reliability needs, while simultaneously minimizing the reliance on GHG-emitting resources for energy and capacity.

MCE’s Preferred Conforming Portfolio
MCE’s PCP is described in detail below and is represented in MCE’s Resource Data Template (RDT), version 3, for the 8 MMT Conforming Portfolio. MCE’s PCP [has been approved by MCE’s Chief Executive Officer and Governing Board] as: (a) reflective of MCE’s actual planned procurement as of the filing of this IRP; (b) consistent with MCE’s statutory obligations; (c) consistent with the Commission’s IRP framework and guidelines, including the Preferred System Plan (“PSP”); (d) consistent with the Commission’s reliability requirements; and (c) consistent with MCE’s current internal procurement plans and policies. MCE’s PCP comes in under its assigned portion of the 8 MMT system emissions targets. MCE’s PCP was approved by MCE’s governing Board on [July 16, 2026] and is being provided to the Commission for certification consistent with Section 454.52(b)(3).

Request for Certification
MCE respectfully requests that the Commission certify MCE’s 2026 IRP.

As both the Legislature and the Commission have recognized, the Legislature has granted CCAs broad authority to procure resources on their customers’ behalf, an authority limited only where “other generation procurement arrangements have been expressly authorized by statute.”4 The Commission has also recognized that the Legislature has granted CCAs autonomy 4 Section 366.2(a)(5).
7 in setting their own rates and managing interactions with their customers.5 As such, the Commission has three primary interests in the CCA IRP process:
● Ensuring that CCA IRPs provide the CCA procurement information that the Commission needs to develop its statewide plan;6
Ensuring that CCAs’ current and planned procurement is consistent with the resource adequacy (“RA”) requirements established pursuant to Section 380;7 and ● Ensuring that each CCA contributes to grid reliability and GHG emissions reductions through the procurement of long-term renewable integration resources. 8 MCE prepared its IRP with these interests in mind and appreciates the Commission's recognition of CCA procurement autonomy and the benefits of a collaborative approach in its certification of MCE’s IRP.
b) Summary of Findings
This narrative provides a detailed description of: (a) the development and content of MCE’s PCP; (b) the PCP’s compliance with applicable requirements; and (c) an Action Plan detailing MCE’s planned next steps to implementing its plan. MCE developed its IRP through the following steps:

1. MCE compiled data for its existing energy-only contracts, bundled energy and capacity contracts, RA capacity contracts, and its share of capacity for allocated Cost Allocation Mechanism (“CAM”) and Demand Response resources and energy from hydro-electric and nuclear allocations;

2. For each IRP planning year, MCE identified its short positions relative to MCE's planning targets in relation to its assigned load forecast;

3. MCE populated the RDT with all current contracts;

4. MCE compiled information on projects for which it is currently negotiating power purchase agreements (“PPA”), including information regarding project status and timing;
5 D.05-12-041 at 5 (“Nothing in the statute directs the CPUC to regulate the CCA’s program except to the extent that its programs may affect utility operations and the rates and services to other customers. For example, the statute does not require the CPUC to set CCA rates or regulate the quality of its services.”); D.19-04-040 at 18 (“[T]he Commission does not approve CCA or ESP rates.”). 6 D.19-04-040 at 17-18 (“The Commission’s portfolio aggregation and evaluation process, which relies of fulfillment of IRP filing requirements by LSEs, is the only process capable of assessing the overall needs of the CAISO grid and meeting the statewide GHG, reliability, and least-cost goals collectively. While LSEs may use their IRP process to meet local planning needs as well, the statewide planning function is the statutorily required process. 7 Section 454.52(b)(3)(C).
8 Section 454.51.
8 5. MCE identified future contracts it expects for new geothermal, storage, and wind generation. MCE prioritized the selection of future resources to ensure that MCE’s overall portfolio of new resources: 1) is varied; 2) is feasible in terms of resource availability; 3) meets all regulatory requirements as well as MCE’s Board adopted policies; and 4) is estimated to minimize upward pressure on customer rates;

6. MCE added generic future contracts with existing resources, including solar, wind and large hydroelectric generators, to help fill its remaining open positions;

7. MCE used the Commission’s Clean System Power (“CSP”) calculator to check the GHG emissions associated with the resulting portfolio to ensure that these emissions are lower than MCE’s assigned emissions benchmark;

8. MCE identified the resulting portfolio as its PCP; and

9. MCE checked its PCP for reliability by comparing the total portfolio Net Qualifying Capacity (“NQC”) against MCE’s forecast RA requirements for the month of September in each year of the planning period.

MCE reached the following findings regarding its PCP:
• MCE’s PCP includes the procurement of the following new resources and nameplate capacities over the course of the planning horizon:
o New wind resources totaling 801 MW;9
o New geothermal resources totaling 96 MW;
o New solar resources totaling 1,624 MW;
o New grid connected battery storage of 803.5 MW; and
o New long-duration storage10 of 1,201.7 MW.
• MCE’s PCP provides for the following overall resource mix in 2045:
o Large hydro-electric of 500 GWh;
o Geothermal of 1,617 GWh;
o California wind of 627 GWh;
o Out-of-state wind of 1,695 GWh;
o California solar of 4,446 GWh;
o Hybrid solar and storage of 254 GWh; and
o Standalone battery storage of -538 net GWh (capacity x duration). • MCE’s PCP would have GHG emissions of 0.35 MMT, 0.27 MMT, 0.20 MMT, and 0.14 MMT in 2030, 2035, 2040, and 2045, respectively. These emissions are lower than MCE’s assigned GHG benchmarks for those years.
• MCE’s PCP meets all Commission-provided reliability metrics. 9 This 801 MW of new wind resources consists of 256 MW in-state and 545 MW out-of-state wind. 10 MCE is currently interested in long-duration storage resources with at least 8 hours of duration at full capacity. 9 • MCE’s PCP is consistent with the Commission’s System Reference Plan and can be used in an 8 MMT (2045) consolidated statewide portfolio.

MCE has selected its PCP as it meets all applicable regulatory requirements and appropriately balances Board directives, MCE’s program goals, cost constraints, reliability, GHG emissions limits, and customer rate impacts. Specifically, the PCP adheres to the current MCE Board policy to achieve 85% renewable energy content for its Light Green offering by 203511 and minimize GHG emissions through use of a combination of renewable energy and other low carbon energy sources. MCE further notes that the internal RPS targets reflected in its PCP represent RPS procurement above the required state minimums, and these targets are subject to change pending future direction from MCE’s Board of Directors. If MCE’s internal RPS targets are materially revised by the Board, those changes will be reflected in MCE’s future procurement-related filings including its IRP, biannual MTR filings, and RPS Procurement Plans.

To implement its PCP, MCE is adopting the Action Plan described in Section IV, below. This Action Plan includes the following steps:
• MCE will conduct an annual “Open Season” Request for Offers (“RFO”) process to solicit offers for new renewable generation and storage projects. These resources are typically secured through long-term PPAs. MCE expects to secure PPAs for new projects in each open season conducted over the next several years.
• MCE will, throughout the year, solicit offers for (i) short-term renewable energy, (ii) large hydro-electric and Asset Controlling Supply (“ACS”), (iii) RA, and (iv) load-hedging products needed to balance the portfolio and adhere to risk limits established through MCE’s risk management policy and practices12. These solicitations can take the form of formal RFO processes, bilateral discussions, and transactions arranged through broker markets.
• MCE will continue to explore the development and offering of customer programs that shed load, including aggregated load shift from business and residential customers. • MCE will provide an annual update to its Board of Directors (or delegated subcommittee) on its progress towards its procurement plan outlined in this IRP. 11 This assumes a certain amount of curtailment as dictated by the CSP. Without the curtailments assigned by the CSP calculator, MCE’s renewable generation would be approximately 93%. To account for curtailment, MCE uses short-term contracts to balance its portfolio and meet its goals and obligations. This ensures that unrealized or curtailed generation is accounted for.
12 MCE Risk Management Policy. https://mcecleanenergy.org/wp-content/uploads/2022/01/Policy_015_MCE_Risk_Management_Policy.pdf. 10 II. Study Design
a) Objectives
MCE had the following objectives in performing the analytical work to develop its PCP and IRP:
• Identify a portfolio that meets MCE’s goals for renewable energy utilization and GHG emission minimization and that has GHG emissions no greater than MCE’s proportional share of the 8 MMT 2045 GHG Emissions Benchmark, as determined using the CSP calculator;
• Identify a portfolio that achieves economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals set forth in Section 454.52(a)(1) (A-I);
• Identify a diverse and balanced portfolio that includes both short-term and long-term electricity and demand reduction and management products; • Identify a portfolio that achieves the RA requirements established pursuant to Section 380 and fully provides MCE’s share of system reliability and renewable integration resources;
• Identify a portfolio that fully complies with all MCE Board-adopted procurement directives;
• Identify portfolios that are fully compliant with MCE’s obligations under the Renewable Portfolio Standard (“RPS”) program; and
• Identify portfolios that are cost-effective and minimize rate impacts on MCE’s customers.
b) Methodology
i. Modeling Tool(s)
In developing its PCP, MCE used modeling tools that quantify portfolio targets for renewable energy content, capacity, and portfolio GHG emissions, as well as physical and financial positions to ensure adherence to MCE’s risk management policies and business practices. MCE uses proprietary models to assess annual, monthly, and hourly open positions taking into account forecasted hourly electric loads and expected deliveries from MCE’s resource portfolio.

Following that, SERV/RESOLVE13 planning assumptions were incorporated into the models to specify a mix of planned resources, including considerations relating to the timing of resource 13 The Strategic Energy & Risk Valuation Model (SERVM) and the Renewable Integration Solutions model (RESOLVE) are energy planning models used by the CPUC to evaluate resource adequacy, renewable integration, and long-term planning of California‘s energy system. 11 acquisition, the type of resources acquired, and the assumed mix of procurement of new and existing resources. The RDTv3 and CSP templates were used to test the portfolio for reliability and GHG emissions. MCE uses a proprietary financial model to project power supply costs and incorporate existing and planned procurement into an overall financial assessment of revenues, costs, and cash flows. MCE also utilizes a commercially available energy trading and risk management system to monitor positions, market exposure, credit exposure, value-at-risk, and other risk management metrics.14
For new resource selection where specific projects have not yet been identified in MCE’s procurement process, MCE relied upon the modeling and assumptions in RESOLVE as well as MCE’s recent procurement experience. Both provide insight into resource availability and cost.

MCE considered resource cost and portfolio fit (i.e., how new resources would complement existing portfolio resources to reliably serve MCE’s load shape, while minimizing GHG emissions) when selecting new resources.

Portfolio GHG emissions were assessed using the Commission’s CSP calculator. ii. Modeling Approach
The modeling approach was to identify a portfolio of resources that meets the objectives outlined above and that considers resource availability under the assumption that other LSEs would procure in a manner generally consistent with the 2025-2026 Transmission Planning Process (TPP) Portfolio with updates. MCE utilized the 2025 Inputs and Assumptions documentation for information on expected cost and availability of new candidate resources and used this information along with its own market insights to guide selection of technology types and timing of procurement for the new resources in the portfolio. As part of this process, MCE adhered to the guiding principles listed below when evaluating alternative modelling strategies and assumptions:
• Mission & Board Policy: Meet Board-approved renewable procurement and emissions targets and comply with all Board-adopted procurement directives; • Regulatory Compliance: Comply with CPUC procurement-related rules and regulations, including procurement orders and RA;
• Affordability: Build a portfolio that ensures stable and affordable rates for MCE customers;
• Risk Management: Incorporate contract terms and lengths and procurement timelines to minimize market risk impacts on MCE customers;
• Technology Diversity: Invest in a diverse portfolio of clean technology types; and 14 Hitachi Energy TRMTracker.
12 • Clean Reliability: Progress towards a cleaner RA portfolio.

Load Forecast
MCE developed its IRP using its assigned load forecast pursuant to the January 16, 2026, Administrative Law Judge’s Ruling Setting Requirements for Individual Integrated Resource Plans Due August 10, 2026 (“Load Forecast Ruling”). MCE’s assigned load forecast used in this IRP is as follows:

Table 1: MCE’s 2023-2045 Assigned Load Forecast
Year Load Forecast (GWh)
2026 5,847.22
2027 5,946.03
2028 5,989.68
2029 6,153.29
2030 6,361.61
2031 6,568.83
2032 6,792.68
2033 7,056.61
2034 7,329.52
2035 7,600.09
2036 7,822.10
2037 8,022.20
2038 8,201.54
2039 8,361.32
2040 8,507.80
2041 8,632.92
2042 8,750.88
2043 8,852.85
2044 8,926.14
2045 8,980.29
Load Shape
In developing its PCP, MCE used the default load shape from the CSP calculator. The use of this load shape does not change MCE’s total annual energy volumes for both load and load modifiers, and these energy volumes remain consistent with MCE’s assigned load forecast. 13 Compiling Existing Resources
To populate its baseline resource templates, MCE added existing resources from the following sources:
● MCE’s existing energy contracts;
● MCE’s existing capacity (RA) contracts;
● MCE’s assigned share of capacity for CAM15 and Demand Response resources; and ● Expected and assumed allocations of GHG-free energy from the Pacific Gas & Electric Company (“PG&E”) portfolio.

Contracts using existing resources are a combination of those currently under contract (existing contracts) and potential future contracts (planned contracts). Reliance on planned purchases of existing resources was constrained to 19.7% of the overall energy portfolio in recognition of the need that significant development of new resources will be necessary to meet the State’s GHG reduction goals and that contracting opportunities with existing resources may become increasingly scarce.

Selecting New Resources
To identify its new resource procurement opportunities, MCE first determined the new resource capacity it intends to add each year and considered candidate resources based on assessments of availability, cost, and portfolio fit. Planned purchases were dispersed across all years in the planning period, although actual procurement throughout the planning horizon will likely deviate from this exact timeline.

A variety of factors were considered in determining the size and composition of the new resource procurement additions reflected in MCE’s PCP plan. These factors include resource need (i.e., open positions relative to planning targets), RPS standards including long-term renewable contracting requirements, RA requirements, the need for incremental RA capacity to contribute to system reliability and renewable integration needs (e.g., incremental procurement orders) balanced with a desire to reduce reliance on natural gas for capacity over time, the potential for technological improvements over time, cost/customer impacts, and risk considerations.

MCE assessed resource availability based on the CPUC’s planning assumptions and inputs and used this information to help guide the timing of procurement of various generation resource types. The CPUC’s RESOLVE modeling helped guide MCE’s selection of new resource types, as 15 MCE is assigned a share of capacity for CAM resources that PG&E is required to procure for reliability purposes on behalf of all customers, and the cost is shared across those customers. 14 did its experience with competitive solicitations for new renewable and storage and RA resources.

Confirming Reliability
MCE’s PCP was evaluated to ensure that sufficient dependable capacity (NQC) is available to meet peak load requirements plus the required planning reserve margin (PRM). Portfolio reliability was evaluated using forward-looking Effective Load Carrying Capacity (ELCC) factors provided by the Commission for each resource type to assess the total NQC of the portfolio relative to MCE’s reliability requirements. This approach ensures MCE’s PCP addresses the expected changes to ELCC factors and NQC of its planned resources and contributes to grid reliability commensurate with its share of system reliability needs.

MCE notes that the ELCCs for battery storage resources degrade precipitously during the planning period, which means that battery resources provide less NQC per MW of nameplate capacity. In order to ensure that its portfolio met the reliability requirements in each year of the planning period, MCE added sufficient short-term RA capacity as needed to supplement capacity from its long-term portfolio. MCE’s PCP was designed to ensure that current incremental RA capacity obligations are met, and that MCE contributes to new resource development to address fossil fuel retirements.

Calculating GHG Emissions
MCE calculated the emissions associated with its PCP using the Commission’s CSP calculator.

The assigned load forecast, default load shapes, and behind-the-meter adjustments were used for this assessment, along with the planned supply portfolio. MCE used standard resource profiles from the Clean System Power calculator. The resulting emissions in each year were checked against the assigned GHG benchmarks. MCE’s PCP results in 2030 emissions of 0.35 MMT, 2035 emissions of 0.27 MMT, 2040 emissions of 0.20 MMT, and 2045 emissions of 0.14 MMT.
iii. Alternative Assumptions
MCE used pricing data gathered from its own solicitation results for Geothermal and Wind in addition to applying a price escalation factor to model potential portfolio costs and bill impacts. 15 III. Study Results
a) Conforming Portfolio
Pursuant to Commission direction,16 MCE is submitting a preferred conforming portfolio that meets MCE’s share of the assigned GHG targets for years 2030, 2035, 2040, and 2045. MCE is not presenting Alternative Portfolios.

Table 1 provides a summary of MCE’s PCP, identifying resources by type and distinguishing between the following procurement categories:
• Existing resources (energy and capacity) that MCE owns or contracts with, consistent with definitions provided in the Resource Data Template; • Existing resources (energy and capacity) that MCE plans to contract with in the future; • Existing resources (capacity) allocated to MCE through the CPUC’s CAM ; • New Resources (energy and capacity) that are under development that MCE is planning to procure; and
• Future new resources (energy and capacity) that MCE is currently planning to procure.

In summary, to meet MCE’s projected 2045 energy demand, MCE has selected a Conforming Portfolio composed of the following resources by 2045:
• Solar, contracted and online: 12 GWh
• Solar, planned existing: 341 GWh
• Solar, planned new: 4,093 GWh
• Hybrid, contracted in development: 254 GWh
• Wind, contracted in development: 223 GWh
• Wind, planned existing: 85 GWh
• Wind, CA, planned new: 319 GWh
• Wind, New Mexico, planned new: 1,193 GWh
• Wind, Wyoming, planned new; 502 GWh
• Large Hydro, planned existing: 500 GWh
• Geothermal, planned existing: 876 GWh
• Geothermal, contracted in development: 158 GWh
• Geothermal, planned new: 583 GWh
• Battery storage: 10,640 MWh dispatch capability
16 Administrative Law Judge’s Ruling Setting Requirements for Individual Integrated Resources Plans Due June 1, 2026. January 16, 2026. https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M595/K085/595085015.PDF 16 Additionally, MCE’s PCP includes capacity-only resources composed primarily of the following resources:
• Cost Allocation Mechanism (CAM) capacity resources: 370 MW • Planned existing natural gas annual average: 522 MW
o Detailed annual planned procurement of natural gas is shown in rows 143 through 162 of MCE’s RDT.

MCE’s portfolio includes a mix of existing and new resources, with production from new resources making up approximately 84% of energy supply by 2045. MCE’s PCP is comprised of a diverse mix of generation resources selected to minimize upward pressure on MCE customer rates while still achieving the State’s GHG-reduction targets and reliability requirements.

Table 2: Summary of MCE's PCP
MCE’s PCP is Consistent with the 2025-2026 TPP Portfolio. The new resources included in MCE’s PCP are consistent with the 2025-2026 TPP Portfolio new resource mix as demonstrated in Table 2.

Table 3: Summary of MCE's Share of TPP Resources
Resource Category TPP Portfolio
(MW)
MCE’s Proportional
Share of TPP New
Resources (MW)
MCE’s PCP (MW)
Geothermal 3,230 93 96
Geothermal
(Enhanced)
674 19 0
Biomass 12 0 0
In-State Wind 10,949 315 256
Out-of-State Wind 19,036 548 545
Offshore Wind - 0 0
Solar 82,732 2,381 1,624
Li-ion Battery (4-hr) 6,758 195 803.5
Li-ion Battery (8-hr) 21,102 607 1201.7
Location Constrained
Storage (12-hr)
8,499 245 0
17 Resource Category TPP Portfolio
(MW)
MCE’s Proportional
Share of TPP New
Resources (MW)
MCE’s PCP (MW)
Geothermal 3,230 93 96
Geothermal
(Enhanced)
674 19 0
Biomass 12 0 0
In-State Wind 10,949 315 256
Out-of-State Wind 19,036 548 545
Offshore Wind - 0 0
Solar 82,732 2,381 1,624
Li-ion Battery (4-hr) 6,758 195 803.5
Li-ion Battery (8-hr) 21,102 607 1201.7
Location Constrained
Storage (12-hr)
8,499 245 0
Overall, Table 2 shows that MCE's PCP is broadly consistent with MCE's proportional share of the TPP new-resource build, with the same core technology set (solar, wind, storage, and geothermal) providing the bulk of new supply. The primary differences are in the composition of that build:
• MCE’s PCP carries less solar than the proportional TPP share (1,624 MW versus 2,381 MW in the TPP);
• MCE’s PCP relies materially more on battery storage—particularly longer-duration (8- hour) storage—than the proportional share (combined 4- and 8-hour PCP total of 2,005 MW versus 802 MW proportional) to meet long duration storage procurement requirements and remain in alignment with the System Reference Plan; • MCE’s PCP includes less in-state wind than the proportional share (256 MW versus 315 MW), while remaining essentially at proportional levels for out-of-state wind (545 MW versus 548 MW); and
• MCE’s PCP also does not assume Enhanced Geothermal (0 MW versus a small proportional share of 19 MW) and does not include the location-constrained 12-hour storage category included in the TPP (0 MW versus 245 MW proportional) due to uncertain cost and availability considerations for these technology types. In addition, MCE has not observed any offers through its solicitations or bilateral offers yet.

However, should this change MCE plans to include the above technologies in its future IRP PCPs.
• MCE’s PCP does not include offshore wind at this time due to current policy direction that has created uncertainty on viability and development timelines. MCE will continue 18 to monitor key indicators of project viability, including port construction, funding availability, and supportive policies, that could signal greater development potential in the future.

Taken together, these differences reflect MCE's emphasis on resources that best match its expected net-load profile and reliability needs as well as resource availability, while maintaining overall alignment with the statewide planning direction reflected in the TPP. • The contracted and planned resources for MCE’s PCP are summarized as follows:
• Daggett_Solar_Generic — Clearway Energy Group, solar (1-axis tracking) paired with battery storage, (San Bernardino County), online, 2023–2038. • Strauss_PCC1_MCE — BayWa RE, new wind (PG&E), Santa Barbara County), online, 2023–2038.
• Golden_Fields_Solar_Generic — Clearway Energy Group, solar (1-axis tracking) paired with battery storage, (Kern County), online, 2025–2040. • Cormorant_Storage_MCE — Arevon, new generic battery storage, (San Mateo County), in development, 2027–2042.
• Key_Storage_LD_MCE — NextEra, new generic battery storage, (Fresno County), in development, 2027–2042.
• Corby_Storage_MCE — NextEra, new generic battery storage, (Solano County), in development, 2027–2042.
• Humboldt House_PCC1_MCE — Humboldt House, new generic geothermal, (Nevada), in development, 2028–2049.
• Allium_PCC1_MCE — Longroad, new generic solar 1axis, (San Benito County), in development, 2031–2051.
• Roccasecca_Storage_MCE — DESRI, new generic battery storage, (Nevada), in development, 2027–2042.
19 • Mulqueeney_Wind_PCC1_MCE — new generic wind ca, (Alameda County), in development, 2028–2048 (COD 2027).
• Desert Harvest_MCE — baseline solar (1-axis tracking), (Riverside County), online, 2020–2040.
• Antelope 2_MCE — AES, baseline solar, (Los Angeles County), online, 2019–2038. • Corcoran_MCE — Onward, baseline solar, (Kings County), online, 2015–2040. • Goose Lake_MCE — Onward, baseline solar, (Kern County), online, 2015–2040. • Great Valley_MCE — RWE, baseline solar, (Fresno County), online, 2018–2032. • Hay_MCE — G2 Energy, Biomass, (Solano County), online, 2018–2033. • Kern Tule_PCC1_1_LT_MCE — Sorenson, Small Hydro, (Kern County), online, 2021– 2035.
• Lincoln_MCE — GenPower, Biomass, (Placer County), online, 2013–2033. • Little Bear 1_MCE — Longroad, baseline solar, (Fresno County), online, 2020–2039. • Little Bear 3_MCE — Longroad, baseline solar, (Fresno County), online, 2020–2039. • Little Bear 4_MCE — Longroad, baseline solar, (Fresno County), online, 2020–2039. • Little Bear 5_MCE — Longroad, baseline solar, (Fresno County), online, 2020–2039. • MCE Solar 1_2.0_MCE — AES, baseline solar, (Contra Costa County), online, 2017–2032. • MCE Solar 1_8.5_MCE — AES, baseline solar, (Contra Costa County), online, 2017–2032. • Mustang_MCE —MN8, baseline solar, (Kings County), online, 2018–2032. • Ostrom_MCE — G2 Energy, Biomass, (Yuba County), online, 2013–2031. • Geysers_MCE — Calpine, Geothermal, (Lake County), online, 2017–2026. • Voyager II_MCE — Terra Gen, baseline wind, (Kern County), online, 2018–2030. • Windpower_PCC1_1_LT_MCE_Update — NextEra, baseline wind, (Riverside County), online, 2025–2039.
• Redwood Landfill_MCE — WM Renewable Energy, Biogas, (Marin County), online, 2017–2037.
• Geysers_PCC1_2_LT_MCE — Calpine, existing generic geothermal, (Sonoma County), online, 2025–2045.
• Buena Vista_PCC1_1_MCE — Leeward, new generic wind ca, (Contra Costa County), in development, 2028–2035.
• Buck_MCE — EDF Renewables, existing generic solar fixed, (Marin County), online, 2018–2040.
• SR Airport_MCE — San Rafael Airport, existing generic solar fixed, (Marin County), online, 2012–2032.
• SR Airport 2_MCE — San Rafael Airport, existing generic solar fixed, (Marin County), online, 2020–2040.
20 • Cooley I_MCE — Rep Energy, existing generic solar fixed, (Marin County), online, 2017– 2037.
• Cost Plus_MCE — Bayway RE, existing generic solar fixed, (Marin County), online, 2016– 2036.
• Freethy 1_MCE — Northshore Solar Partners LLC, existing generic solar fixed, (Marin County), online, 2016–2036.
• Freethy 2_MCE — Northshore Solar Partners LLC , existing generic solar fixed, (Marin County), online, 2016–2036.
• Cooley_DRES Quarry 2.4_MCE — DRES Quarry, LLC, existing generic solar fixed, (Marin County), online, 2017–2037.
• Oakley RV & Boat Storage_MCE — California Solar Innovators Inc dba Calsolar, existing generic solar fixed, (Contra Costa County), online, 2018–2038. • Soscal Ferry Solar C_MCE — Renewable Properties LLC, existing generic solar fixed, (Napa County), online, 2020–2040.
• Soscal Ferry Solar D_MCE — Renewable Properties LLC, existing generic solar fixed, (Napa County), online, 2020–2040.
• American Canyon Solar A_MCE — Renewable Properties LLC, existing generic solar fixed, (Solano County), online, 2019–2039.
• American Canyon Solar B_MCE — Renewable Properties LLC, existing generic solar fixed, (Solano County), online, 2019–2039.
• American Canyon Solar C_MCE — Renewable Properties LLC, existing generic solar fixed, (Solano County), online, 2019–2039.
• Silveira Ranch A_MCE — Renewable Properties LLC, existing generic solar fixed, (Marin County), online, 2021–2041.
• Silveira Ranch B_MCE — Renewable Properties LLC, existing generic solar fixed, (Marin County), online, 2021–2041.
• Silveira Ranch C_MCE — Renewable Properties LLC, existing generic solar fixed, (Marin County), online, 2021–2041.
• Lake Herman_PCC1_1_LT_MCE — Renewable Properties LLC, baseline solar (fixed-tilt), (Solano County), online, 2021–2041.
• EO Products_MCE — Small world trading co, existing generic solar fixed, (Marin County), online, 2018–2038.
• Byron Hot Springs_PCC1_2_LT_MCE — existing generic solar fixed, (Contra Costa County), online, 2023–2043.
• Oakley Phase 3_PCC1_1_LT_MCE — existing generic solar fixed, (Contra Costa County), online, 2022–2042.
21 • Byron Highway_PCC1_1_LT_MCE — existing generic solar fixed, (Contra Costa County), online, 2022–2042.
• Fallon_PCC1_1_LT_MCE — existing generic solar fixed, (Sonoma County), online, 2023– 2043.
• Napa Self Storage_PCC1_1_LT_MCE — existing generic solar fixed, (Napa County), online, 2023–2043.
• CMSA_Updated_PCC1_2_LT_MCE — existing generic biogas landfill gas, (Marin County), online, 2022–2032.
• 26SB 8me_PCC1_1_MCE — existing generic solar fixed, (Kern County), online, calendar year 2027.
• TEA_PCC1_4_MCE — existing generic solar fixed, (Kern County), online, 2025–2026. • TEA_PCC1_13_MCE — existing generic wind, (Fresno County), online, calendar year 2026.
• BP_PCC1_1_MCE — existing generic solar fixed, (Fresno County), online, 2025–2026. • Townsite_PCC1_1_MCE — Arevon, distributed solar, (Nevada), online, 2025–2027. • SDG&E_PCC1_1_MCE — existing generic wind, (Kern County), online, calendar year 2026.
• ARICA_PCC1_1_MCE — existing generic solar fixed, (Riverside County), online, 2024– 2026.
• GPC_PCC1_1_LT_MCE — Calpine, existing generic geothermal, (NorthCoastNorthBay), online, 2027–2037.
• RESI_RA_2_NS_MCE — Resi Station, LLC, existing generic dr, (California), online, 2023– 2032.
22 • Conflitti Jr_PCC1_DAC_1_LT_MCE — White Pine Renewable, existing generic solar fixed, (Fresno County), online, 2026–2046.
• Conflitti_PCC1_DAC_2_LT_MCE — White Pine Renewable, baseline solar, (Fresno County), online, 2026–2046.
• CES Electron Farm_RA_1_NS_MCE — White Pine Renewable, baseline solar, (Fresno County), online, 2026–2046.
• WAPA_BR_2_MCE — existing generic instate large hydro, (California), online, 2025– 2054.
• SENA_CF_16_MCE — Shell, existing generic instate large hydro, (Siskiyou County), online, 2025–2027.
• CONSTEL_ACS_1_MCE — Constellation, existing generic nw hydro, (Oregon), online, 2026–2027.
• PG&E_Hydro_7_MCE — Pacific Gas and Electric Company, existing generic instate large hydro, (Plumas County), online, calendar year 2026.
• PG&E_Hydro_8_MCE_Allocation — Pacific Gas and Electric Company, existing generic instate large hydro, (Plumas County), online, 2026–2045. • PG&E_Nuke_2_MCE_Allocation — Pacific Gas and Electric Company, existing generic nuclear, (Plumas County), online, 2026–2030.
• SENA_CF_17_MCE — Shell, existing generic instate large hydro, (Plumas County), online, calendar year 2027.
• CCSF_PCC1_Sell_1_MCE — CleanPowerSF, baseline solar, (Kings County), online, 2022– 2026.
• EBCE_PCC1_Sell_2_MCE — Ava Community Energy, baseline solar, (Kings County), online, calendar year 2026.
• CAM - DR Allocation — Pacific Gas & Electric, existing generic dr, online, 2023–2045. • CAM - Peaker Allocation — Pacific Gas & Electric, existing generic peaker, online, 2023– 2045.
• CAM - Storage — Pacific Gas & Electric, existing generic battery storage, online, 2023– 2045.
23 • Other CAM — Pacific Gas & Electric, existing generic combined cycle, online, 2023– 2045.
• LT Geothermal 1 — new generic geothermal, planned new, 2032–2052. • LT Solar 1 — new generic solar 1axis, planned new, 2030–2050. • LT Storage 1 — new generic battery storage, planned new, 2030–2050. • LT Wind Out of State 1 — new generic wind oos aznm, planned new, 2030–2050. • LT Geothermal 2 — new generic geothermal, planned new, 2035–2055. • LT Solar 2a — new generic solar 1axis, planned new, 2033–2053. • LT Storage 2a — new generic battery storage, planned new, 2033–2053. • LT Solar 2b — new generic solar 1axis, planned new, 2034–2054. • LT Storage 2b — new generic battery storage, planned new, 2034–2054. • LT Solar 2c — new generic solar 1axis, planned new, 2035–2055. • LT Storage 2c — new generic battery storage, planned new, 2035–2055. • LT Wind CA 2 — new generic wind ca, planned new, 2035–2055. • LT Solar 3a — new generic solar 1axis, planned new, 2038–2058. • LT Solar 3b — new generic solar 1axis, planned new, 2039–2059. • LT Storage 3b — new generic battery storage, planned new, 2039–2059. • LT Solar 3c — new generic solar 1axis, planned new, 2040–2060. • LT Storage 3c — new generic battery storage, planned new, 2040–2060. • LT Wind Out of State 3a — new generic wind oos aznm, planned new, 2036–2056. • LT Wind Out of State 3b — new generic wind oos wy, planned new, 2040–2060. • LT Storage 4a — new generic battery storage, planned new, 2043–2058. • LT Solar 4c — new generic solar 1axis, planned new, 2045–2060. • LT Wind Out of State 4 — new generic wind oos aznm, planned new, 2045–2060. • ST Solar — existing generic solar 1axis, planned existing, 2028–2045. • ST Wind — existing generic wind, planned existing, 2028–2045. • ST Large Hydro — existing generic instate large hydro, planned existing, 2035–2045. • LT Storage 0 — new generic battery storage, planned new, 2030–2029. • LT LD Storage 1 — new generic battery storage, planned new, 2032–2052. • GPC_PCC1_1_LT_MCE_renewal — CALPINE, existing generic geothermal, (NorthCoastNorthBay), planned existing, 2037–2047.
• Generic CCGT RA_2026 — existing generic combined cycle, planned existing, calendar year 2026.
• Generic CCGT RA_2027 — existing generic combined cycle, planned existing, calendar year 2027.
24 • Generic CCGT RA_2028 — existing generic combined cycle, planned existing, calendar year 2028.
• Generic CCGT RA_2029 — existing generic combined cycle, planned existing, calendar year 2029.
• Generic CCGT RA_2030 — existing generic combined cycle, planned existing, calendar year 2030.
• Generic CCGT RA_2031 — existing generic combined cycle, planned existing, calendar year 2031.
• Generic CCGT RA_2032 — existing generic combined cycle, planned existing, calendar year 2032.
• Generic CCGT RA_2033 — existing generic combined cycle, planned existing, calendar year 2033.
• Generic CCGT RA_2034 — existing generic combined cycle, planned existing, calendar year 2034.
• Generic CCGT RA_2035 — existing generic combined cycle, planned existing, calendar year 2035.
• Generic CCGT RA_2036 — existing generic combined cycle, planned existing, calendar year 2036.
• Generic CCGT RA_2037 — existing generic combined cycle, planned existing, calendar year 2037.
• Generic CCGT RA_2038 — existing generic combined cycle, planned existing, calendar year 2038.
• Generic CCGT RA_2039 — existing generic combined cycle, planned existing, calendar year 2039.
• Generic CCGT RA_2040 — existing generic combined cycle, planned existing, calendar year 2040.
• Generic CCGT RA_2041 — existing generic combined cycle, planned existing, calendar year 2041.
• Generic CCGT RA_2042 — existing generic combined cycle, planned existing, calendar year 2042.
• Generic CCGT RA_2043 — existing generic combined cycle, planned existing, calendar year 2043.
• Generic CCGT RA_2044 — existing generic combined cycle, planned existing, calendar year 2044.
• Generic CCGT RA_2045 — existing generic combined cycle, planned existing, calendar year 2045.
25 Table 4: MCE's 2045 PCP Resources
Resource
Category
Under
Development
Online Planned
Existing
Planned
New
Under
Review
Total
Battery Storage
(MWh Energy
Capacity)
- - 10,640 - 10,640
Geothermal
(GWh)
158 - 876 583 1,617
Hybrid or
Paired Solar and
Battery (GWh)
254 - - - - 254
Large Hydro
(GWh)
- 500 0 - - 500
Solar California
(GWh)
0 12 341 4,093 - 4,446
Wind California
(GWh)
223- - 85 319 0 627
Wind New
Mexico (GWh)
- - - 1,193 - 1,193
Wind Wyoming
(GWh)
502 502

b) Preferred Conforming Portfolio
In accordance with Section 454.51(b)(3), the resource mix in MCE’s PCP achieves “economic, reliability, environmental, security, and other benefits and performance characteristics that are consistent with the goals set forth in [Section] 454.51(a)(1)].” These benefits and characteristics are discussed below.
26 Meeting GHG Reduction Goals
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(A) goal of meeting the Commission’s GHG reduction targets. The 2030, 2035, 2040, and 2045 GHG are summarized in Table 5.

Table 5: Emissions Results for MCE's PCP
2030 2035 2040 2045
Assigned GHG
Emissions
Benchmark
(MMT)

0.51 0.39 0.33 0.17
2026 IRP PCP
Calculated GHG
Emissions
(MMT)

0.35 0.27 0.20 0.14
Procuring Eligible Renewable Energy
MCE’s PCP achieves results and performance characteristics consistent with the goals of Sections 454.52(a)(1)(B) & (F) of ensuring that portfolios are composed of at least 60% eligible renewable resources and displacing fossil fuels within the state. In 2030, MCE’s PCP portfolio would consist of 81% renewable generation eligible under the RPS program, after accounting for resource curtailments. In 2045, MCE’s PCP would consist of 92% eligible renewable generation after accounting for resource curtailments. The planned proportion of renewable energy in the PCP exceeds the minimum 60% RPS requirement, consistent with MCE’s internal policies and the need for additional non-emitting resources to meet the assigned GHG limits.

MCE primarily procures renewable resources through the use of long-term PPAs and energy storage service agreements. To supplement its core procurement of PCC1 resources under long-term contracts, MCE currently engages in short-term contracts for standalone products including specified renewable energy, CAISO energy, and RA to balance and optimize its PCP. To the extent MCE’s Board directs changes to MCE’s procurement strategy, those changes will be reflected in future MCE filings.

Minimizing Bill Impact
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(D) goal of minimizing the impact of planned procurement on ratepayers’ bills. MCE prioritizes use of renewable energy and low carbon emitting resources, reliability, and cost 27 competitiveness. MCE anticipates that bill impacts will be minimized during its planned portfolio transition through the pursuit of a diversified resource mix that seeks to minimize exposure(s) that could otherwise occur by overemphasizing resources located within specific geographic areas, relying on a limited subset of technology types and/or purchasing from a limited pool of suppliers/developers, amongst other considerations.

MCE also considers the risks associated with the costs of grid congestion and renewable resource curtailments due to negative pricing, which is of particular concern for solar resources.

MCE has carefully considered and incorporated energy storage opportunities within its resource mix, which should promote grid reliability during California’s transition to an increasingly clean and renewable energy mix while reducing the potential for unforeseen costs due to negative pricing and curtailments
While actual procurement volumes and prices are expected to vary from what in included in MCE’s PCP is expected to vary, if MCE were to build and bring online all the resources included in its PCP (per the exact planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information derived from the CPUC’s RESOLVE and MCE’s pricing experiences from prior solicitations, MCE modelled the following affordability and ratepayer impacts:
• MCE’s generation rate17 would increase annually by 5% on average. This estimate is nominal and not adjusted for inflation.
• By 2045, MCE’s rates would cumulatively increase by 18.80 cents/kilowatt-hour (kWh), a 150% increase to the current generation rate.

Ensuring System and Local Reliability
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(E) goal of ensuring system and local reliability on both a near- and long-term basis.

The PCP meets system RA requirements as detailed in Section III.f. The PCP would provide 17 Generation rate refers to the Residential E-TOU-C rate plan based on a weighted average rate of customer usage across seasons (summer/winter) and time-of-use (on-peak/off-peak) periods. 28 adequate energy storage and RA capacity to meet MCE’s generation needs during non-solar generating hours.

MCE currently anticipates that it will meet a portion of its reliability needs during the planning period through short term, capacity-only contracts with natural gas plants, and this is reflected in its PCP. This finding is consistent with the CPUC’s RESOLVE and SERVM modeling showing the need to maintain existing fossil-fueled resources online for reliability purposes. The declining ELCC factors for battery storage resources indicated by these studies are additional contributing factors to this reliance in order to meet CPUC reliability targets. Over the planning period, the proportion of fossil fuel contracts, including CAM resources, that MCE uses for capacity purposes decreases relative to its entire portfolio from 75% currently to 45% in 2045. The natural gas resources included in MCE’s PCP do not supply MCE with energy and do not contribute to MCE’s portfolio emissions. MCE’s PCP includes a significant expansion of grid-connected battery storage resources which will support system and local reliability over the planning horizon.

Ensure that at least 65% of RPS Procurement is From Long-Term Contracts Consistent with Section 454.52(a)(1)(F), MCE is on pace to meet the requirement that 65% of its RPS procurement must come from contracts of 10 years (long-term) or more for each compliance period. Additionally, the significant majority of the resources shown in MCE’s PCP are expected to be acquired through long-term contracts. MCE expects to continue to procure renewable energy through short-term contracts when opportunities present themselves for cost-efficient procurement and to minimize portfolio risk. When doing so, MCE would reduce any remaining dependency on system power, and MCE plans to secure the bulk of its portfolio via long-term contracts.

Strengthening the Bulk Transmission and Distribution Systems MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(G) goal of strengthening the diversity, sustainability, and resilience of the bulk transmission and distribution systems. At this time, MCE does not own, operate, or maintain any bulk transmission or distribution assets. However, MCE’s procurement of strategically located renewable generation, prioritization of local renewable generation, demand-side management efforts, and investment in distribution-side resources all serve to enhance the sustainability and resiliency of the bulk transmission and distribution systems.

MCE’s PCP relies on procurement from a variety of resource types as well as storage resources incorporated in hybrid/co-located solar and storage configuration. MCE believes that the complementary nature of solar plus storage resources allows for better use of the existing transmission system.
29 Enhancing Demand-Side Energy Management
MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(H) goal of enhancing demand-side energy management. MCE’s PCP includes MCE’s allocation of capacity through the demand-side management programs operated by PG&E, as well as MCE’s own demand response resource and virtual power plant programs. The demand response resource is shown in row 79 of MCE’s RDT.
• MCE’s VPP Strategy
A Virtual Power Plant (VPP) is a network of distributed energy resources (DERs) that work together as a distributed and aggregated resource. The system functions similarly to a traditional power plant but uses advanced technology to optimize energy production, storage, and consumption. By integrating resources — such as rooftop solar, batteries, smart thermostats, heat pumps, and EV chargers — VPPs enhance electricity distribution for optimized and sustainable energy use, especially during peak hours.

MCE’s VPP initiatives include both:

Ø Fully dispatchable systems, allowing MCE direct control for precise management.

Ø Non-dispatchable systems that use price signals to encourage customers to reduce or optimize their energy use.

These strategies, coupled with performance-based incentives and automated signals, contribute significantly to stabilizing the grid to prevent power outages while reducing costs and greenhouse gas emissions. Our approach to the VPP is deeply rooted in equity, ensuring that advanced energy technologies are not only accessible but are also actively deployed in low-income and historically underserved communities.
• Richmond VPP Pilot
In 2022, MCE was asked to join a collaborative effort to develop a VPP pilot in the City of Richmond, one of California’s environmental justice communities. The pilot uses networked DERs to shift participant demand in real time. MCE uses a first-of-its-kind, custom-built enterprise-level DER Management System (eDERMS), licensed in perpetuity to MCE, to shift and shape customer load to times of day when the energy is cleanest and least expensive for participants. Customers are compensated for their load shifting based on MCE’s VPP Tariff.

Participants include previously abandoned, blighted homes acquired by Richmond Community Foundation (RCF) Connects and then fully rehabbed into 21st century all-electric homes (Zero Net Carbon Ready, ZNCR). These ZNCR homes are sold for less-then-market rates to first-time, lower-income homeowners to simultaneously support grid reliability while aiding in community revitalization - showcasing how technology and equity can work hand in hand. Other 30 participants include lower income residents for whom MCE previously subsidized solar costs, as well as local business and multi-family facilities, which received energy system improvements.

As of January 2026, the VPP Pilot successfully integrated 9 DER types into the DERMS. The Pilot includes 3 ZNCR homes that were fully rebuilt and sold to first-time, lower-income homebuyers. 33 residential participants and 1 multifamily participant (with 144 units) are in the pipeline, with 12 DER types installed so far.
• VPP FLEX
The California Energy Commission subsequently awarded MCE a $5 million VPP FLEX grant to expand the VPP pilot to MCE’s entire service area. This will allow MCE to add other eligible customer programs into the VPP effort. Through VPP FLEX, MCE will update the eDERMS platform to be OpenADR 3.0 certified, integrate the VPP with CAISO markets to capture new revenues for the agency, and implement a value-sharing plan between MCE, participants, and service providers who bring flexible load to the program.

Through VPP FLEX, MCE aims to:

1. Adapt MCE’s existing programs to be VPP-ready.

2. Integrate third party or customer-owned DERs into MCE’s VPP ecosystem by leveraging open-source communication protocols and certifications.

3. Deploy new DERs at commercial, public, industrial, and other non-residential facilities.

Ultimately, the VPP will provide load-shifting and cost reductions, benefitting all customers while simultaneously providing a local load-shift resource for the agency, which can be used to offset procurement costs, manage peak demand, and generate new revenues through market participation. MCE will begin enrolling new participants and growing its engagement with VPP Partners in 2026, with a target of enrolling 3MW of flexible load by the end of the project. • MCE Sync
MCE Sync, launched in 2021, is an app-based load-shifting program that helps customers automate electric vehicle (EV) charging at home using the cleanest and cheapest energy. The program allows EV households to benefit from Vehicle-to-Grid Integration (VGI) functionality and incentives that reduce the cost of EV charging at home, with a focus on low- to moderate-income populations. This includes an enrollment bonus, significant energy savings, and incentives for charging during the lowest-carbon hours.

In 2024, MCE launched a Dynamic Pricing Pilot aimed at saving drivers’ money while testing how managed charging paired with dynamic signals can improve grid stability, lower energy costs, and boost renewable energy use in California. In 2025, MCE launched a pilot offering free smart home EV chargers to income-qualified customers for whom vehicle compatibility is a barrier to enrolling in MCE Sync. As of May 2026, MCE Sync has enrolled over 4800 active EVs, 31 saving enrolled customers an average of $10 per month. The program has also enrolled 600 EVs into the Dynamic Pricing Pilot. Further, in 2026 MCE completed integration of the MCE Sync with its eDERMS, unlocking enhanced transparency into load and potential for future optimization of charging loads.

MCE expects to continue its pilot offering free smart home chargers to income-qualified customers through 2026 and is currently evaluating a Phase 2 launch in late 2026 dependent on additional funding from the CEC.
• Peak FLEX Market
Launched June 2021, MCE’s Peak FLEX Market supports grid reliability by encouraging program participants to reduce demand during the peak hours of 4 - 9 p.m. This program works with an open market of qualified aggregators, each with a portfolio of projects delivering their own demand-flexibility solutions. The program pays aggregators for daily load-shifting out of peak periods, measuring results through Advanced Metering Infrastructure (AMI) data and individual device data.

Beginning in 2027, the Peak FLEX Market program will re-launch with a focus on daily load shifting. The program will focus on managed EV charging, Battery Electric Stationary Storage (BESS), and building-automation controls. MCE will leverage existing programs to increase participants and enhance program impacts, incorporating existing equipment as well as newly installed assets.

Minimizing Localized Air Pollutants with Emphasis on Disadvantaged Communities MCE’s PCP achieves results and performance characteristics consistent with the Section 454.52(a)(1)(I) goal of minimizing localized air pollutants and other GHG emissions with early priority on disadvantaged communities (DACs). MCE’s PCP relies primarily on renewable generation and would have low-GHG and localized-air-pollutant emissions. Further, MCE’s PCP minimizes MCE’s reliance on unspecified system power, instead opting for renewable generation, hydro generation, local energy storage, and local demand side reduction programs.

Results from the CSP calculator indicate the following localized air pollutants associated with MCE’s PCP in 2045:
• NOx: 12 tonnes/yr
• PM 2.5: 14 tonnes/yr
• SO2: 1 tonne/yr
32 These emissions derive from unspecified system energy that is assigned to the portfolio during certain hours when load exceeds the supply from emissions-free resources in accordance with the CSP calculator’s hourly accounting.

Maintaining portfolio diversity, including resources procured by DWR Consistent with Section 454.52(a)(1)(J), MCE’s PCP prioritizes resource diversity across multiple dimensions (technology, location, procurement timing, counterparty) as a fundamental risk-management strategy, yielding a portfolio with production characteristics that generally align with MCE’s load shape. This alignment reduces reliance on system energy—and its resulting emissions—while also reducing CAISO market exposure. These considerations are necessarily balanced against availability and cost concerns. Under current market conditions, clean baseload resources are limited in availability and come with high costs. Consequently, while MCE’s PCP includes a diverse portfolio of resources, it leans heavily on solar and storage, consistent with the System Reference Plan. Potential technological improvements or incorporation of resources procured by the Department of Water Resources can be accommodated and could displace resources currently planned for in MCE’s PCP. The procurement timing articulated in MCE’s PCP provides flexibility to adapt to such changes.

Portfolio Comparison
Table 6 provides a summary of the planned new nameplate capacity included in MCE’s 2022 IRP for the 25 MMT by 2035 scenario and the 8 MMT by 2045 PCP included in this IRP. Changes across the two portfolios reflect changes in actual procurement conducted by MCE in response to actual portfolio needs. In addition, the difference in planned resources takes into account changing market realities for new resources and the decline in NQC values for resources such as battery storage. Across both scenarios, MCE continues to meet its GHG Emissions and renewable procurement targets. Additional details are provided in Section X on Existing Resource Planning.

Table 6: Comparison of 8 MMT by 2045 PCP and 25 MMT by 2035 PCP from MCE's 2022 IRP Resource Type Planned New Nameplate
Capacity (MW),
8 MMT by 2045 PCP
Planned New Nameplate
Capacity (MW),
25 MMT by 2035 Scenario in
2022 IRP
Wind, in-state 256 100
Wind, out-of-state 545 70
Offshore Wind - 95
Geothermal 96 109
33 Solar (California, imported) 1624 222
Short-duration storage,
Li-ion battery (4hr)
803.5 559
Long-Duration Storage (8hr) 1201.7 90
Demand Response - 15
c) GHG Emissions Results
GHG emissions associated with MCE’s PCP are shown in Table 7. As previously noted, the emissions associated with MCE’s PCP are lower than the assigned GHG limits as required for a conforming portfolio.

Table 7: MCE's PCP GHG Emissions
Emissions
Total
Unit 2030 2035 2040 2045
CO2 MMt/yr 0.35 0.27 0.20 0.14
d) Local Air Pollutant Minimization and Disadvantaged Communities i. Local Air Pollutants
Local pollutant emissions associated with MCE’s PCP are shown below:

Table 8: MCE's PCP Local Pollutant Emissions
Emissions
Total
Unit 2030 2035 2040 2045
PM2.5 tonnes/yr 54 22 14 12
SO2 tonnes/yr 18 7 1 1
NOx tonnes/yr 118 51 38 14
Local air pollutants associated with MCE’s electricity mix are projected to decrease throughout the planning period. As described in MCE’s Action Plan, MCE intends to reduce its reliance on system power by procuring renewable and other low GHG-emitting resources identified in its 34 PCP. MCE actively seeks out power supply technologies that minimize air pollutants, with an emphasis on fully renewable technologies.
ii. Focus on Disadvantaged Communities
MCE’s PCP is fully consistent with the goal of minimizing local air pollutants, with early priority on DACs. As part of MCE’s mission to reduce GHG Emissions, MCE focuses on procurement efforts on low-emissions resources. Most generation facilities that are under contract for PPAs are non-emitting resources, such as solar and wind. MCE does contract with natural gas-fired power plants for RA but aims to reduce reliance on these contracts for RA over time as additional renewable resources and batteries can be relied upon.

As identified by CalEPA’s designation, Table 10 provides a summary of the DACs MCE serves within its service area. Out of all generation facilities that MCE contracts with for either energy, capacity, or both, 24 facilities are within a DAC, 14 facilities are within a 5-mile radius of a DAC, and 10 facilities are within a 10-mile radius of a DAC. Table 9 provides a summary of the contracts within a DAC or within a 5-mile radius of a DAC.

Table 9: Summary of MCE contracted facilities within a DAC or within a 5-mile radius of a DAC Tract Zip Code County Nearby City
Total
Population
MCE
Contract ID
Resource
Non-GHG Gas Emitting Resources located within a Disadvantaged Community (DAC) or within 5 miles of a DAC 6071009400 92311
San
Bernardino Barstow 3262
Daggett_Sola
r_Generic SISPRG_2_DS3SR2
6019007801 93234 Fresno
Unincorporated
Fresno County
area 2731
Key_Storage_
LD_MCE
_NEW_GENERIC_B
ATTERY_STORAGE
6031001300 93212 Kings
Unincorporated
Kings County
area 4811
Corcoran_M
CE
CORCAN_1_SOLAR
2 6029003304 93251 Kern
Unincorporated
Kern County
area 3358
Goose
Lake_MCE
GOOSLK_1_SOLAR
1 6029003304 93251 Kern
Unincorporated
Kern County
area 3358
Great
Valley_MCE TRNQL8_2_ROJSR1
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Little Bear
1_MCE LTBERA_1_LB1SR1
35 6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Little Bear
3_MCE LTBEAR_1_LB3SR3
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Little Bear
4_MCE LTBEAR_1_LB4SR4
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Little Bear
5_MCE LTBEAR_1_LB4SR5
6031001601 93239 Kings
Unincorporated
Kings County
area 4101
Mustang_MC
E
MSTANG_2_SOLAR
4 6013392200 94806
Contra
Costa Richmond 11304
Freethy
1_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6013392200 94806
Contra
Costa Richmond 11304
Freethy
2_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6013302005 94561
Contra
Costa Oakley 7290
Oakley RV &
Boat
Storage_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6013302005 94561
Contra
Costa Oakley 7290
Oakley Phase
3_PCC1_1_LT
_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Conflitti
Jr_PCC1_DAC
_1_LT_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
Conflitti_PCC
1_DAC_2_LT
_MCE
PNOCHE_2_CEFSR
1 6029006500 93505 Kern California City 4501
Voyager
II_MCE
VOYAGR_2_VOYW
D3
Federal Tribal
Areas: Agua
Caliente
Indian
Reservation - - - -
Windpower_
PCC1_1_LT_
MCE_Update GARNET_1_WINDS
6077005206 95304
San
Joaquin
Unincorporated
San Joaquin
County area 26742
Mulqueeney
_Wind_PCC1
_MCE
_NEW_GENERIC_
WIND_CA
6029005204 93285 Kern
Unincorporated
Kern County
area 5963
Kern
Tule_PCC1_1
_LT_MCE KRNCNY_6_UNIT
6019008302 93640 Fresno
Unincorporated
Fresno County
area 7406
CES Electron
Farm_RA_1_
NS_MCE
PNOCHE_2_CEFSR
1 36
6075061000 94134
San
Francisco San Francisco 4839
Cormorant_S
torage_MCE
_NEW_GENERIC_B
ATTERY_STORAGE
6095251902 94589 Solano Vallejo 6173
American
Canyon Solar
A_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6095251902 94589 Solano Vallejo 6173
American
Canyon Solar
B_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6095251902 94589 Solano Vallejo 6173
American
Canyon Solar
C_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6095251200 94590 Solano Vallejo 3663
Lake
Herman_PCC
1_1_LT_MCE BAHIA_2_LKHSR1
6077003900 95206
San
Joaquin
Unincorporated
San Joaquin
County area 1518
Byron Hot
Springs_PCC1
_2_LT_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
6077003900 95206
San
Joaquin
Unincorporated
San Joaquin
County area 1518
Byron
Highway_PCC
1_1_LT_MCE
_EXISTING_GENERI
C_SOLAR_FIXED
GHG Gas Emitting Resources located within a Disadvantaged Community (DAC) or within 5 miles of a DAC 6095253500 94571 Solano
Unincorporated
Solano County
area 10676 Hay_MCE PEABDY_2_LNDFL1
6019003900 93630 Fresno
Unincorporated
Fresno County
area 6477
WELLHEAD_R
A_3_POF_M
CE AGRICO_7_UNIT
6085512602 95020 Santa Clara
Unincorporated
Santa Clara
County area 2404
CALPINE_RA_
44_NS_MCE GILRPP_1_PL1X2
6013309000 94565
Contra
Costa Pittsburg 3546
CALPINE_RA_
68_NSF_MCE LMEC_1_PL1X3
6029003304 93251 Kern
Unincorporated
Kern County
area 3358
Midway_RA_
1_NSF_MCE SUNSET_2_UNITS
6029003304 93251 Kern
Unincorporated
Kern County
area 3358
Sunrise
Power_RA_1
_SSF_MCE SUNRIS_2_PL1X3
6037980002 90745
Los
Angeles Carson 0
Watson_RA_
1_SS_MCE ARCOGN_2_UNITS
Auburn
Rancheria - - - - Lincoln_MCE
PLSNTG_7_LNCLN
D
37 6071009117 92301
San
Bernardino
Unincorporated
San Bernardino
County area 8697

HIGHDESERT
_RA_3_SSF_
MCE HIDSRT_2_UNITS
Agua
Caliente
Indian
Reservation - - - -
SENTINEL_RA
_1_LF_MCE SENTNL_2_CTG1
Table 10: DACs Served by MCE
Census Tract Nearby
City
California
County
ZIP Code Total
Population
MCE
Residential
Accounts in
Census
Tract
MCE Non-Residential
Accounts in
Census
Tract
MCE
Accounts in
Census
Tract
06013305000 Antioch Contra
Costa
94509 6561 3 95 98
06013314103 Bay Point Contra
Costa
94565 5629 1529 58 1587
06013314104 Bay Point Contra
Costa
94565 9278 2122 87 2209
06013336201 Concord Contra
Costa
94520 4056 1125 15 1140
06013365002 North
Richmond
Contra
Costa
94801 5590 1201 121 1322
06013302005 Oakley Contra
Costa
94561 7290 2009 170 2179
06013313102 Pittsburg Contra
Costa
94565 4595 1437 103 1540
06013313101 Pittsburg Contra
Costa
94565 7178 2474 368 2842
06013311000 Pittsburg Contra
Costa
94565 5329 1451 43 1494
06013314102 Pittsburg Contra
Costa
94565 6561 1160 25 1185
06013310000 Pittsburg Contra
Costa
94565 6257 1620 105 1725
06013312000 Pittsburg Contra
Costa
94565 2243 608 70 678
06013309000 Pittsburg Contra
Costa
94565 3546 1229 147 1376
06013375000 Richmond Contra
Costa
94801 4897 1066 79 1145
38 06013373000 Richmond Contra
Costa
94801 4468 880 79 959
06013377000 Richmond Contra
Costa
94801 7323 2038 137 2175
06013392200 Richmond Contra
Costa
94806 11304 2790 150 2940
06013381000 Richmond Contra
Costa
94804 6521 1738 166 1904
06013376000 Richmond Contra
Costa
94801 6245 1551 68 1619
06013380000 Richmond Contra
Costa
94804 5931 2759 277 3036
06013379000 Richmond Contra
Costa
94804 7003 1510 169 1679
06013382000 Richmond Contra
Costa
94804 8159 1543 92 1635
06013358000 Rodeo Contra
Costa
94572 6285 1577 128 1705
06013366002 San Pablo Contra
Costa
94806 6627 1587 58 1645
06013368002 San Pablo Contra
Costa
94806 3782 935 85 1020
06013369001 San Pablo Contra
Costa
94806 7254 1914 195 2109
06013368001 San Pablo Contra
Costa
94806 4817 1226 73 1299
06013366001 San Pablo Contra
Costa
94806 4514 1109 30 1139
06013364002 Tara Hills Contra
Costa
94806 5531 1659 26 1685
06013327000 Unincorpo
rated
Contra
Costa
County
area
Contra
Costa
94520 7430 1618 703 2321
06013320001 Unincorpo
rated
Contra
Costa
County
area
Contra
Costa
94553 3671 1101 194 1295
06013315000 Unincorpo
rated
Contra
Costa
94520 3862 1057 567 1624
39 Contra
Costa
County
area
06013314200 Unincorpo
rated
Contra
Costa
County
area
Contra
Costa
94565 7748 1443 37 1480
06095252502 Fairfield Solano 94533 2106 583 215 798
06095252402 Unincorpo
rated
Solano
County
area
Solano 94534 5549 1491 309 1800
06095253500 Unincorpo
rated
Solano
County
area
Solano 94571 10676 258 190 448
06095250801 Unincorpo
rated
Solano
County
area
Solano 94592 4135 934 37 971
06095251901 Vallejo Solano 94589 5119 1537 52 1589
06095251600 Vallejo Solano 94590 2580 1008 92 1100
06095250900 Vallejo Solano 94590 2654 1060 236 1296
06095251802 Vallejo Solano 94589 2770 898 311 1209
06095250701 Vallejo Solano 94590 3529 737 156 893
06095251000 Vallejo Solano 94590 2654 1071 39 1110
06095251200 Vallejo Solano 94590 3663 1023 167 1190
06095251500 Vallejo Solano 94590 4326 1300 283 1583
06095251902 Vallejo Solano 94589 6173 1462 39 1501
In total, MCE serves 69,582 customer accounts located within DACs. This represents approximately 11.6% of MCE’s 600,000 customer accounts.

MCE’s programs illustrate that MCE takes an expansive view of its responsibilities in this area and takes efforts to minimize air pollutions impacts in disadvantaged communities, not only in its own service area, but across the entire state. MCE is dedicated to reducing pollution impacts and encouraging the development, health, and prosperity of DACs within and outside our 40 service area. Our commitment is reflected in the practices, programs, and policies described below and in our Action Plan.

Green Access Program
MCE serves 5,585 low-income customers in DACs through its Disadvantaged Communities Green Tariff (DAC-GT) program as of 2026. The DAC-GT program supplies 100% renewable power to customers located in a DAC with an accompanying 20% bill discount. MCE’s program is considered fully enrolled and has been allocated 8.25 MW of capacity.

MCE prioritizes enrollment of customers who live in the highest scoring DACs, are currently participating in either the California Alternate Rates for Energy (CARE), Family Electric Rate Assistance (FERA) discount program, and Arrearage Management Plan (AMP).

MCE’s Conflitti solar project came online on January 27, 2026 and serves 4.64 MW of MCE’s capacity. MCE launched a solicitation for new-build solar resources to fulfill its remaining capacity of 3.608 MW on February 23, 2026, and bids are currently being evaluated. The remaining enrolled customers are currently served by Conflitti, located in Fresno, CA and an interim resource, Goose Lake, which is in Lost Hills, CA.

Equity in Power Purchasing
MCE’s Open Season solicitation encourages suppliers to consider community benefits and equity metrics when submitting offers. Some of the optional elements that MCE solicits in offers include:
• Support for educational programs, environmental justice initiatives, and workforce development and training initiatives;
• Participation of contractors, subcontractors, or businesses owned by disabled veterans; • Projects located in a designated DAC or employing workers living in a designated DAC; and
• Use of components and materials manufactured or assembled by local suppliers or in the United States.

In late 2020, when issues related to the use of forced labor for solar equipment production in Xinjiang, China, were reported, MCE incorporated new language into its PPA term sheets and contracts that prohibit MCE from contracting with facilities that rely on equipment or resources built with forced labor. This language was incorporated into MCE’s Open Season solicitations, DAC-GT solicitations, PPAs, and will continue to be an MCE procurement requirement. 41 e) Cost and Rate Analysis
In developing its PCP, MCE strives to balance affordability, reliability, and decarbonization while meeting all MCE Board adopted policies as well as all regulatory requirements. MCE also prioritizes reliability and seeks to build a portfolio that minimizes risks related to transmission congestion, curtailments, project development, and other uncertainties that increase the potential for unanticipated costs. MCE endeavors to achieve this balance as cost effectively as possible to maintain competitive rates and to the extent feasible reduce upward pressure on customer rates and bills.

With these goals in mind, the resources in MCE’s PCP were selected for least cost and best portfolio fit based on associated emissions, delivery profile, and reliability. MCE considers both the direct resource costs (e.g., contract price) as well as the value of each resource in its portfolio, taking into account the different resource characteristics of the various portfolio options.

MCE engages in competitive solicitations for resource selection and makes resource decisions based on the prices offered and negotiated. MCE has observed notable instability in offered resource prices over time as market conditions and external events, such as procurement orders, trade tariffs, tax policies, and supply chain conditions impact resource costs at any given time. If these events persist, or additional external events (e.g., new procurement orders) occur shifting price risks onto LSEs, the average portfolio costs may instead continue to increase in excess of MCE’s current projections. While MCE’s PCP provides a helpful framework for procurement decisions going forward, MCE must remain flexible to respond to market conditions or technological changes as circumstances change. MCE will take steps to minimize bill impacts, but near-term rate increases may be necessary to accommodate increased procurement costs.

In evaluating new resource commitments, MCE seeks generation and/or storage projects that meet portfolio fit considerations and that have positive net present value in consideration of expected contract costs and the value of the energy, reliability, and environmental attributes provided by the project. Such projects help reduce consumer costs relative to alternative sources of energy and capacity.

New resources were selected for the PCP with the goal of minimizing ratepayer impacts, while meeting reliability and environmental policy goals. MCE’s plan diversifies across different renewable and low-carbon generation technologies with the goal of reducing use of system energy, thereby reducing market risk and emissions. MCE selected new resources that provide 42 reliability and low emissions (e.g., geothermal) and other carbon-free technologies that have low expected costs (e.g., wind), which in conjunction with resources already under contract provide a least-cost, best-fit portfolio solution. While not the lowest cost resource option, geothermal resources were included in the PCP to provide reliability benefits from additional clean, firm resources. These resources have relatively low GHG emissions, and their ability to reliably produce energy on a near 24X7 basis warrants a role despite higher costs. Technological diversification in use of resources capable of providing firm energy reduces ratepayer risk that could arise from overdependence on new technologies such as long duration storage. The PCP includes lower cost wind resources to help minimize ratepayer impacts while meeting environmental and reliability objectives. MCE’s PCP also aims to minimize exposure to volatile natural gas and system power prices, and the billing impacts that can result from periodic spikes in fossil fuel prices.

MCE modeled the expected portfolio costs of its PCP to evaluate cost and rate impacts on customers. The associated costs assumed in the model were a blend of the RESOLVE model price indicators and MCE’s own internal data from prior solicitation offers. MCE also applied price escalators on highly sought after resources to adjust for scarcity pricing. It must be noted that the projected portfolio costs are dependent on assumed costs for new resources, that are subject to considerable uncertainty.

Portfolio Cost Analysis
The graph below presents the portfolio cost analysis results. Based on the assumptions described above, MCE expects its overall portfolio costs to increase by an annual average of Portfolio costs remain relatively flat through 2028 before steadily increasing beginning in 2029, primarily driven by the addition of new resources at higher costs than existing resources.

This rise in cost is further compounded by increasing reliability requirements on MCE’s portfolio and decreasing marginal ELCCs.
43 Figure 2: Average portfolio cost over the planning period for MCE's PCP Rate Analysis
While actual procurement volumes and prices are expected to vary from what is included in MCE’s PCP is expected to vary, if MCE were to build and bring online all the resources included in its PCP (per the exact planning timeline) and directly pass through the incremental procurement costs to customers, based on current pricing information derived from the CPUC’s RESOLVE and MCE’s pricing experiences from prior solicitations, MCE modelled the following affordability and ratepayer impacts:
• MCE’s generation rate18 would increase annually by 5% on average. This estimate is nominal and not adjusted for inflation.
• By 2045, MCE’s rates would cumulatively increase by 18.80 cents/kilowatt-hour (kWh), a 150% increase to the current generation rate.

The rate impacts described above are intended for illustrative incremental portfolio and ratepayer impact analysis only. Critically, MCE does not currently have a rate mechanism to directly pass through power procurement costs to customers via rate increases. Any future rate 18 Generation rate refers to the Residential E-TOU-C rate plan based on a weighted average rate of customer usage across seasons (summer/winter) and time-of-use (on-peak/off-peak) periods.
44 changes would require approval from its Board of Directors, and actual net cost and rate impacts would be dependent on all costs and revenues.

Figure 3: Rate Impact of MCE's PCP
f) System Reliability Analysis
MCE’s PCP meets or exceeds applicable reliability requirements as demonstrated in Figure 4 and Table 11. The CPUC’s reliability metric shows expected contribution to reliability for each resource by year, taking into consideration the ELCC of each resource type. Expected reductions in the ELCC for many resource types require increases in new generation capacity to maintain reliability levels. By 2045, approximately half of the PCP’s NQC is expected to come from new resources and approximately 68% of total nameplate capacity will be from new resources, primarily solar and battery storage. The following table and chart from the Reliability – Planning sheet of the RDT show load and resource by contract status for the PCP that includes total reliability need (effective MW), total supply (effective MW), and net capacity position (effective MW) for all study years.

Table 11: MCE's Reliability Need, Total Supply, and Net Capacity Position (2026 - 2045) 45 Figure 4: MCE's Capacity by Contract Status (2026 - 2045) Existing Resource Planning
Since its launch in 2010, MCE has been committed to building and expanding access to in-state renewable generation resources. This is reflected by the approximately 2928 MW of new-build renewable generation that MCE has contributed to building across California, and the additional approximately 860 MW (nameplate) of new build that MCE currently has under contract to come online in the next six years. Further, as demonstrated in MCE’s PCP, which covers the full planning horizon, MCE will continue to drive significant new resource development, which will have a corresponding decrease in MCE’s planned use of existing resources. Over the planning period, the majority of supply in the PCP portfolio is planned to be from new resources, with minimal reliance on existing resources. Planned contracts with existing resources are generally for resource types that have historically been available. MCE has chosen these resources because of their lower delivery risks compared to new resources (i.e., existing resources are not subject to development risks that often result in delays or outright cancellation of planned new resources) and in recognition of the beneficial role that short-term purchases from existing resources can play in facilitating portfolio flexibility.

In MCE’s portfolio, the primary existing resources not already under contract with MCE are in-state large hydro, wind, and solar resources. These resources have been generally available to- 46 date and have met the needs of MCE’s customers for carbon-free energy at competitive prices with minimal operational risks.

The proportionate use of planned purchases from existing resources included in the PCP is broadly similar to what was included in the 25 MMT by 2035 PCP from the 2022 IRP, though the current PCP shows a somewhat higher share of existing resources in the near term. Focusing on 2035, the last year of the 2022 planning period, existing resources make up about 55% of supply in the current PCP versus about 41% in the 2022 IRP — roughly 2,420 GWh existing versus 3,553 GWh new in the 2022 IRP, and roughly 4,172 GWh existing versus 3,440 GWh new in the current PCP. This shift partly reflects the maturation of the portfolio: 4 projects with a total of 310 MW in generation and 152 MW of storage that were categorized as new builds in the 2022 IRP have since been brought online and now count toward the existing baseline in the current PCP. By 2045, however, the PCP is overwhelmingly a new-resource portfolio. Existing baseline supply (currently existing contracts that will be part of MCE’s supply throughout the planning period) declines to about 1,815 GWh, while new builds dominate at roughly 7,325 GWh (~20% / 80%).
g) Hydro Generation Risk Management
In developing its PCP, MCE took the following three steps to manage the risk of reduced hydro-electric availability due to in-state drought:

1. MCE reduced its overall reliance on large hydro-electric generation by adopting ambitious targets for renewable energy (which excludes large hydro-electric). More specifically, MCE’s PCP in 2045 consists of 92% eligible renewable generation, with less than 6% coming from large hydro-electric generation.

2. To the extent hydro-electric fits into the portfolio, MCE has an established network of Pacific Northwest hydro suppliers, including entities that have substantial ACS energy volumes. As a result of these substantial ACS volumes, suppliers are able to sell MCE reliable, firm volumes.

3. MCE can opt to take deliveries of hydropower outside of the CAISO and schedule/import such volumes into the CAISO on its own, as a purchasing-selling entity registered with the North American Electric Reliability Corporation (“NERC”)-affiliated North American Energy Standards Board (“NAESB”). This substantially increases MCE’s flexibility as a counterparty and therefore provides MCE with increased access to greater volumes of non-California hydro-electric resources from suppliers that may not be willing, themselves, to be the importer of record.
47 To the extent that hydro supply is unavailable, MCE would plan to use other sources of low-carbon or carbon-free energy, which may include additional qualifying renewable energy.

Considering the relatively small volume of planned large hydro, the cost impact of supply unavailability is limited. Moreover, the PSP’s hydro-electric energy resources are planned as energy-only. As such, there would be no direct reliability impacts to MCE’s PSP in the event of drought, although there may be system-wide reliability impacts to the extent that other LSEs utilize large hydro-electric resources for capacity purposes. h) Long-Duration Storage Planning
MCE is planning significant new battery storage capacity to help balance load and supply as it integrates a greater percentage of renewable energy into its supply mix and continues to reduce reliance on natural gas generation supply. MCE sees a greater need and role for long-duration storage as the grid continues to evolve. To address this need, MCE is procuring to meet its long-duration storage requirement under D.21-06-035 (i.e., 29 MW of NQC) and anticipates procuring an additional 395 MW NQC of long-duration storage resources in the 2030 to 2035 timeframe. MCE observed that the System Reference Plan includes increasing amounts of eight-hour battery storage and relatively static amounts of four-hour battery storage over the planning period. MCE has similarly planned to increase its use of long-duration storage over time. Planned solar plus storage projects beginning with the 2030-2035 procurement timeline include eight-hour battery storage. This represents a change from the 2022 IRP in which most of the battery storage was planned as four-hour duration.

In MCE’s view, battery storage technology is currently the most commercially viable technology to qualify for this long-duration attribute. However, MCE is also evaluating other technologies that have long-duration storage capability. Technology performance risk is the biggest unknown at present because, with the exception of pumped hydro storage, there is little track record for utility scale, long-duration storage. MCE expects rapid technological improvement in battery storage as the industry continues to scale up and anticipates declining costs in the longer-term.

In the short-term, however, costs are increasing, and project opportunities are limited, particularly when the procurement is facing accelerated procurement timelines. These factors may impact the pace at which MCE adds storage to its resource portfolio. i) Clean Firm Power Planning
MCE has prioritized acquisition of clean firm resources beyond what is required under existing Commission procurement orders. Despite higher costs, clean firm resources provide reliable capacity and a higher-value energy delivery profile as compared to solar and other intermittent 48 resources. MCE is planning for use of geothermal resources over time (a total of 96 MW over the planning period). This is a drop of 13 MW from the 2022 IRP due to increased scarcity of eligible geothermal. Unfortunately, the supply of geothermal and clean firm resources is very limited in California, and the cost of new-build resources is significantly higher. Clean firm energy imported from other balancing areas is complicated by transmission availability and the need to obtain equivalent Maximum Import Capability (“MIC”) through the CAISO to utilize the capacity under the RA program. Despite these challenges to their expanded use, clean firm resources are important contributors to reliability and offer operational attributes that cannot be replicated by current technologies of storage or other resource types. To develop these resources cost-effectively and efficiently, California LSEs will need the commitment of regulatory agencies and CAISO to facilitate this resource development, ensuring regulatory procedures and requirements align with market realities and that the transmission infrastructure necessary for this development is available and accessible to California LSEs. j) Non-CAISO, including Out-of-State, Wind Planning
For new out-of-state wind energy projects, MCE’s PCP plans for total new additions of 545 MW starting in 2030 and continuing through the planning period. This planned procurement generally follows the 2026 – 2040 timeline and relative scale reflected in the CPUC’s RESOLVE modeling results for selected out-of-state wind builds, with the full modeled potential of approximately 19 GW reached by 2045.

To date, MCE has observed, through its solicitations, opportunities to contract with New Mexico wind resources delivered via the SunZia transmission project. However, the availability of Interconnection Agreement Requests (“IARs”) remains a constraining factor for New Mexico wind, and transmission limitations appear to be constraining the availability of wind resources from Wyoming, Idaho, and other states. Compared to the 2022 IRP, the current PCP includes similar amounts of out-of-state wind after adjusting for the larger load reflected in the current PCP. Transmission still remains the most significant risk to MCE’s planned use of out-of-state wind.

The preference of New Mexico wind in the PCP is not intended to reflect a definitive procurement plan for that area, as other locations for future wind projects may also be viable.

New Mexico was relied upon as the most likely source based on MCE’s review of wind projects offered in recent solicitations, including opportunities that utilize existing firm transmission routes into the CAISO. MCE also observes significant potential in the PSP for wind located in Wyoming and Idaho, along with transmission projects that are being planned to allow delivery 49 of these resources to California as reflected in its PCP. These developments may create opportunities to contract for new wind from those areas in the 2030 timeframe, provided that the planning and construction of necessary transmission infrastructure proceeds expeditiously.

Without timely transmission development, it will be difficult to secure deliverability and import allocation rights for these resources, which could make such projects unattractive to California LSEs.
k) Offshore Wind Planning
MCE did not include plans for offshore wind in its PCP pending further progress on development of this resource type. Potential Department of Water Resources contracts of offshore wind energy have not been assumed, but MCE can adapt future plans as needed to incorporate these resources. Offshore wind appears to be a high potential resource with relatively high-capacity factors and RA values. At this time, the costs of offshore wind development and maintenance infrastructure are largely unknown. As such, cost and development timelines pose the greatest risk to utilization of this resource. Despite these and other possible near-term barriers to progress on this front, MCE is monitoring the issue as it evolves and procurement of offshore wind becomes feasible. l) Transmission Planning
This section describes new generation projects that are under development and planned projects that have been specifically identified through MCE’s procurement processes where there is sufficient locational specificity that could be useful to the transmission planning process.

Projects Under Development
• Mulqueeney Wind Energy, LLC
This is a new build 80 MW wind project. The expected commercial operation date (COD) is in 2027, and MCE intends to apply this resource towards its procurement requirements under D.21-06-035 & D.23-02-040. The project is located in Alameda County. The interconnection queue positions are Q-1277 & Q-1459. All transmission upgrades needed for this project have been completed. The Mulqueeney Wind project is represented in the 8 MMT RDT as incremental capacity. Please refer to row 15 of the unique_contracts tab in MCE’s RDT. 50 • Allium Hybrid, LLC
This is a new-build hybrid project located in San Benito County that pairs 110 MW of solar with 110 MW four-hour battery storage. The project has an expected COD of May 2031 and MCE intends to apply this resource towards its procurement requirements under D.21-06-035 & D.23-02-040. The interconnection queue position for this resource is Q-1921, and the project will connect via Crazy Horse Canyon-Hollister 115 kV Line Tap. Transmission upgrades needed for this project are expected to be completed in December 2030. These transmission upgrades are described in Appendix A to the Large Generator Interconnection Agreement (“LGIA”) and include participating transmission owner (i.e., Southern California Edison (SCE)) reliability network upgrades. The Allium project is represented in the 8 MMT RDT as incremental capacity. Please refer to row 9 of the unique_contracts tab in MCE’s RDT. • Humboldt House Geothermal, LLC
This is a new-build 20 MW geothermal project located in Pershing County, Nevada. The project has an expected COD of February 2028, and MCE intends to apply this resource towards its procurement requirements under D.21-06-035. Transmission upgrades are currently being evaluated and an updated Interconnection Agreement is expected in August 2026. The Humboldt House project is represented in the 8MMT RDT as incremental capacity. Please refer to row 8 of the unique_contracts tab in MCE’s RDT.
• Buena Vista Energy, LLC
This is a refurbished 38 MW wind project. The project has an expected COD in January 2028 and is located in Contra Costa County. The interconnection queue position is Q-21, and the project will connect at the Buena Vista Substation, 230kV Bus. Buena Vista project is represented in the 8 MMT RDT as incremental capacity. Please refer to row 37 of the unique_contracts tab in MCE’s RDT.
• Corby Energy Storage, LLC
This is a new 100 MW four-hour battery storage project to be located in Solano County. The project is contracted to come online in April 2027. Permitting for the project may delay the project’s online date. MCE intends to apply this capacity towards its procurement requirements under D.23-02-040. The interconnection queue position is Q-1270, and the project will connect at the Vaca-Dixon Substation. Corby is represented in the 8MMT RDT as incremental capacity.

Please refer to row 7 of the unique_contracts tab in MCE’s RDT. • Key Energy Storage, LLC
This is a new 35 MW eight-hour battery storage project with an expected COD of April 2027 and will be located in Fresno County. MCE intends to apply this resource towards its procurement 51 requirements under D.21-06-035. The interconnection queue position is Q-1479, and the project will connect at the Gates Substation, 500kv Bus. Key is represented in the 8 MMT RDT as incremental capacity. Please refer to row 6 of the unique_contracts tab in MCE’s RDT. • Cormorant Energy Storage, LLC
This is a new 250 MW four-hour battery storage project with an expected COD of August 2028 and will be located in San Mateo County. MCE intends to apply this resource towards its procurement requirements under D.21-06-035. The interconnection queue position is Q-1552, and the project will connect at the Martin Substation. Cormorant is represented in the 8 MMT RDT as incremental capacity. Please refer to row 5 of the unique_contracts tab in MCE’s RDT. • Roccasecca BESS, LLC
This is a new 126.59 MW four-hour storage project with an expected COD of March 2027 and will be located in Clark County, Nevada. MCE intends to apply this resource towards its procurement requirements under D.21-06-035 & D.23-02-040. The interconnection queue position is Q-1347, and the project will connect at the Sloan Canyon Switching Station. The Roccasecca storage project is represented in the 8 MMT RDT as incremental capacity. Please refer to row 14 of the unique_contract tab in MCE’s RDT.

Projects Under Review
MCE has launched the Open Season 2026 RFO process to execute long-term supply contracts with projects that align with MCE’s portfolio goals and needs. Offers from prospective projects are due in July 2026, and the MCE team intends to evaluate offers throughout Q3 2026, culminating in executed contracts by the end of Q1 2027. MCE will also continue to accept and evaluate bilateral offers for resources that address portfolio needs. In addition to standard procurement processes that add new resources to MCE’s portfolio, we are considering multiple initiatives to optimize resources within our existing portfolio. This includes adding BESS to existing solar-only resources to relieve persistent congestion and curtailment, negotiating with counterparties to purchase contracted products prior to the original PPA start date, and evaluating a PPA extension to secure continued long-term renewable energy supply.

Planned New (Generic) Projects
The Planned New projects included in the PCP are generic in nature and generally follow locational assumptions in the System Reference Plan. Locations and technology resource types are subject to change as MCE advances in its procurement. 52 IV. Action Plan
m) Proposed Procurement Activities and Potential Barriers To achieve its PCP over the planning horizon, MCE plans to steadily procure volumes at regular intervals, allowing MCE to keep within its established position limits while avoiding concentrated procurement during any particular market environment. This is consistent with MCE’s risk-management approach to spread out potential cost risks that may be at play in the market in a given year, allowing MCE to optimally procure. At a high level, MCE plans to procure renewables and storage, geothermal, large hydro-electric and ACS, RA (including incremental capacity required by the Commission) and load-hedging products. MCE’s goal is to procure such products in a cost-effective manner, achieve emissions and reliability objectives, and support a well-balanced resource portfolio.

To support this goal, MCE considers the following strategies:

Optimizing Existing Procurement
As MCE considers its long-term resource needs, it evaluates options in its future PPAs for expanding or upgrading existing generating facilities to increase their output. Expanding existing facilities may provide additional generation at reduced costs with lower risk of project failure, as the need for transmission upgrades, distribution upgrades, and additional permitting activities may be reduced. However, MCE has experienced challenges receiving deliverability status for new-build resources due to transmission-upgrade issues. MCE continues to engage with stakeholders and developers to evaluate the feasibility of such expansions for implementation.

Annual Energy Solicitations
In addition to periodic joint solicitations, MCE will run targeted solicitations in the upcoming years to further optimize its portfolio needs. Such solicitations can provide MCE with the flexibility to meet MCE’s unique portfolio needs and obligations.

MCE considers the deliverability characteristics of its resources, including the expected delivery profile, available capacity and dispatchability attributes, if any, associated with each of its generating resource and/or supply agreements. MCE also reviews the respective risks associated with short- and long-term purchases as part of its forecasting and procurement processes, including, but not limited to, transmission availability, MIC allocation, and exposure to global supply chain and market forces.
53 MCE’s efforts will lead to a more diverse resource mix, address grid integration issues, improve the probability of project delivery, and provide value to MCE’s member communities through reduced costs and support in achieving planned procurement objectives.

MCE has a well-established procurement process to steadily achieve its PCP over the next twenty years (i.e., by 2045), which consists of the following ten key activities:
• Load forecasting based on the number and types of customers, potential service territory expansions, opt-out rates, electrification trends, demand-side resources and weather;
• Integrated resource planning based on load forecasts, renewables and emissions targets, agency-wide budgetary considerations and customer rate implications, long-term contracting requirements and goals for new steel in the ground, grid reliability needs and capacity requirements, market price hedging needs and goals for local resources, local resiliency and local workforce development; • Calculating open positions and interim volumetric needs based on MCE’s risk management policies;
• Soliciting volumetric needs through RFOs, bilateral discussions or brokers; • Evaluating offers using a combination of proprietary and public models; • Negotiating power purchase agreements, enabling agreements and confirms – including credit provisions and collateral requirements – and seeking Board approval, as required, to execute such agreements;
• Managing pre-COD executed contracts and monitoring progress towards key development milestones (such as interconnection status, deliverability studies, siting, zoning, permitting, financing, construction, commercial operation, etc.) • Managing post-COD executed contracts: obtaining generation forecasts, bidding/scheduling resources into the CAISO markets, validating and paying invoices, etc.;
• Bidding/scheduling MCE’s load into the CAISO markets; and • Regulatory compliance reporting.

With respect to the fourth activity, MCE plans to conduct an “Open Season” RFO in the first half of each year for new renewable generation and storage projects. Over the next several years, MCE anticipates that the majority of its Open Season solicitations will result in the execution of long-term PPAs for new renewables and/or storage. MCE anticipates that such projects will achieve commercial operation within 3-5 years of contract execution. In its solicitations for long-term renewable energy and storage, MCE imposes numerous bid requirements on interested respondents, addressing a variety of considerations and identifying the best qualified suppliers of MCE’s long-term renewable energy needs. Such requirements include:
a) Overall quality of response, inclusive of completeness, timeliness, and conformity; b) Price and relative value within MCE’s supply portfolio; 54 c) Project location and local benefits, including local hiring and prevailing wage considerations;
d) Project development status, including but not limited to progress toward interconnection, deliverability, siting, zoning, permitting, and financing requirements;
e) Qualifications, experience, financial stability, and structure of the prospective counterparty (including its ownership);
f) Environmental impacts and related mitigation requirements, including impacts to air pollution within communities that have been disproportionately impacted by the existing generating fleet;
g) Potential impacts to grid reliability and congestion; h) Acceptance of MCE’s standard contract terms; and
i) Development milestone schedule, if applicable.

In addition to its Open Season, MCE plans to solicit offers periodically throughout each year for the following products: short-term renewable energy, large hydro-electric, ACS, and RA. MCE will also solicit offers periodically for load-hedging products to balance its portfolio and adhere to position limits established through the agency’s risk management approach.

MCE's risk management approach aims to procure low-cost supply that is diverse across technologies, production profiles, project sizes and locations, counterparties, lengths of contract, and timing of market purchases.

Considering MCE’s forward load obligations and existing supply commitments, MCE’s procurement process aims to balance supply and demand, as well as cost/rate stability and overall budgetary impacts, while leaving flexibility to take advantage of market opportunities and technological improvements as they arise. MCE monitors its open positions separately for each renewable generating technology, as well as for GHG-free resources, conventional resources, and its aggregate supply portfolio. MCE maintains portfolio coverage targets of up to 100% of expected customer energy requirements in the near-term (0 to 2 years). Typically, MCE has progressively larger open positions in the mid- to long-term, consistent with generally accepted industry practices.

In addition to its planned and proposed procurement activities, MCE also takes into consideration the various barriers that may impact its planned renewable projects. Some of the potential barriers for each of the new resources identified in MCE’s PCP include:
• New Wind: The current market conditions have made new in-state wind resources scarce, which has led to a price premium and escalated cost risks on any available in-state wind resources. In addition, the transmission constraints and limited MIC 55 allocation for out-of-state wind has made it difficult to negotiate and plan for new resources due to the uncertainty of deliverability.
• New Geothermal: Due to the scarcity of new geothermal projects in-state and the uncertainty of deliverability and transmission for out-of-state geothermal projects, there has been unprecedented competition for available geothermal, placing upward pressure on contract prices. If this trend continues, it may impact MCE’s ability to procure new geothermal resources in the near-term. Next-generation geothermal technologies are also being considered by MCE to provide the same benefits of renewable baseload capacity provided by conventional geothermal. • Hybrid Resources: Currently, most hybrid resources primarily consist of intermittent resources like solar paired with storage resources. As solar is highly affected by global supply chain issues, most planned projects are facing upward cost pressures and delays to project development timelines.
• Storage: Similarly, global supply chain issues and the scarcity of the raw materials required for battery production present risk and uncertainty in prices and expected delivery dates that may negatively impact MCE’s planned portfolio and budgeted costs.

Additionally, Foreign Entity of Concern (FEOC) restrictions imposed by the One Big Beautiful Bill Act (OBBBA) are forcing developers to reevaluate their battery supply vendors to ensure compliance with the latest Internal Revenue Service (IRS) guidance, enabling their projects to receive all available federal tax credits. This procurement challenge introduces additional pricing risk into projects.

MCE continuously monitors market developments and engages with various market stakeholders, including the Commission, CAISO, and other CCAs, to strategize and find solutions to the barriers and risks associated with new clean energy procurement. Throughout the planning period, MCE will proactively evaluate its planned procurement and make adjustments to meet its portfolio needs, as determined by MCE’s Board, and its operational and compliance needs.
i. Resources to meet IRP mandated procurement requirements, including D.21-06-035 and D.23-02-040
MCE continues to actively pursue, procure, and develop energy storage projects—both standalone and paired with renewable generation—to meet its Mid-Term Reliability (“MTR”) requirements pursuant to D.21-06-035, D.23-02-040, and D.26-02-057. To identify additional projects that meet its MTR needs and IRP procurement obligations, MCE uses annual solicitations, formal RFIs and RFOs, and bilateral opportunities with project developers, as described in Section IV.a), above.

MCE’s procurement requirements and the progress towards meeting them are displayed in 56 Table 12 below. MCE has a small need remaining for firm, zero-emitting generation resources under D.21-06-035, and is making progress towards fulfilling its requirements under D.26-02- 057.

Table 12: MCE's Procurement Requirements ordered under MTR Procurement Procurement Order D.21-06-035 D.23-02-040
Year ordered online 2023 2024 2025 2026 2026 2026 2026 2027 2030 2031 2032 Incremental NQC 58 173 43 29* 29* 72 61 61 60 60 60
Description
Gen-ericGen-ericGen-eric
LDS
Clean
Firm
DCPP
replac
emen
t
Gen-ericGen-ericGen-eric**Gen-eric**Gen-eric**
Resource Type
Daggett
Solar
project
Hybrid 58.1 7.7 45.9
Strauss Wind 15.4
Golden
Fields
solar
project
Hybrid 43 34.4 19.5 6.9
Geysers
Geother
mal

6.5 Cormora
nt
storage
BESS 149.9 41.6
Corby
storage
BESS 22
Key
LDS
BESS

30.5 Humbold
t House
Geother
mal

18.6 Allium Hybrid 35.2
Roccasec
-ca
BESS 54.3 11.7
Mulquee
-ney
Wind 26.3 1.7
Total 58.1 173 43 30.5 25.1 80.3 61.1 61.1 60 36.9 0
*LLT resource requirements are divided into half from long-duration storage and half from firm, zero-emitting generation resources.
**All procurement must come from clean energy-generating resources, and one quarter of the procurement must come from either clean, firm power, or long duration energy storage. 57 Description of Resources Used to Meet IPR Procurement Mandates • Geysers
Geysers is a new build 7 MW geothermal project located in Sonoma County, California. The project achieved commercial operation on June 1, 2025, and MCE intends to apply this resource toward its long-lead-time, firm-clean procurement requirements under D.21-06-035 and D.23- 02-040. The Geysers project is represented in the 8 MMT RDT as incremental capacity as stated in row 36 of the unique_contracts tab in MCE’s RDT.
• Golden Fields Solar IV
Golden Fields Solar IV is a new-build hybrid project located in Kern County that pairs 100 MW of solar with 92 MW of four-hour battery storage. The project achieved commercial operation on August 8, 2025, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035 and D.23-02-040, including the subset of MCE’s requirement intended to replace the Diablo Canyon Power Plant (“DCPP”). The Golden Fields Solar IV project is represented in the 8 MMT RDT as incremental capacity as stated in row 4 of the unique_contracts tab in MCE’s RDT.
• Mulqueeney Wind Energy, LLC:

Mulqueeney Wind Energy, LLC is a new build 80 MW wind project located in Alameda County.

The project has an expected commercial operation date in 2027, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035 and D.23-02-040. The interconnection queue positions are Q-1277 and Q-1459, and all transmission upgrades needed for the project have been completed. The Mulqueeney Wind project is represented in the 8 MMT RDT as incremental capacity as stated in row 15 of the unique_contracts tab in MCE’s RDT.
• Allium Hybrid, LLC
Allium Hybrid, LLC is a new-build hybrid project located in San Benito County that pairs 110 MW of solar with 110 MW of four-hour battery storage. The project has an expected COD of May 2031, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035 and D.23-02-040. The interconnection queue position is Q-1921, and the project will connect via the Crazy Horse Canyon-Hollister 115 kV Line Tap. Transmission upgrades are expected to be completed in December 2030 and are described in Appendix A to the Large 58 Generator Interconnection Agreement (“LGIA”), including participating transmission owner reliability network upgrades. The Allium project is represented in the 8 MMT RDT as incremental capacity as stated in row 9 of the unique_contracts tab in MCE’s RDT. • Humboldt House Geothermal, LLC
Humboldt House Geothermal, LLC is a new build 20 MW geothermal project located in Pershing County, Nevada. The project has an expected COD of February 2028, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035. Transmission upgrades are currently being evaluated and an updated Interconnection Agreement is expected in August 2026. The Humboldt House project is represented in the 8 MMT RDT as incremental capacity as stated in row 8 of the unique_contracts tab in MCE’s RDT. • Corby Energy Storage, LLC
Corby Energy Storage, LLC is a new 100 MW four-hour battery storage project located in Solano County. The project is contracted to come online in April 2027, although permitting may delay the online date, and MCE intends to apply this capacity toward its procurement requirements under D.23-02-040. The interconnection queue position is Q-1270, and the project will connect at the Vaca-Dixon Substation. Corby is represented in the 8 MMT RDT as incremental capacity as stated in row 7 of the unique_contracts tab in MCE’s RDT. • Key Energy Storage, LLC
Key Energy Storage, LLC is a new 35 MW eight-hour battery storage project located in Fresno County. The project has an expected COD of April 2027, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035. The interconnection queue position is Q-1479, and the project will connect at the Gates Substation, 500 kV Bus. Key is represented in the 8 MMT RDT as incremental capacity as stated in row 6 of the unique_contracts tab in MCE’s RDT.
• Cormorant Energy Storage, LLC
Cormorant Energy Storage, LLC is a new 250 MW four-hour battery storage project located in San Mateo County. The project has an expected COD of August 2028, and MCE intends to apply this resource toward its procurement requirements under D.23-02-040. The interconnection queue position is Q-1552, and the project will connect at the Martin Substation. Cormorant is represented in the 8 MMT RDT as incremental capacity; please refer to row 5 of the unique_contracts tab in MCE’s RDT.
59 • Roccasecca BESS, LLC
Roccasecca BESS, LLC is a new 126.59 MW four-hour storage project located in Clark County, Nevada. The project has an expected COD of March 2027, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035 and D.23-02-040. The interconnection queue position is Q-1347, and the project will connect at the Sloan Canyon Switching Station. The Roccasecca project is represented in the 8 MMT RDT as incremental capacity; please refer to row 14 of the unique_contract tab in MCE’s RDT • Daggett Solar
Daggett Solar is a new-build hybrid project located in San Bernandino County that pairs 110 MW of solar with 60 MW of four-hour battery storage. The project achieved commercial operation on August 25, 2023, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035, including the subset of MCE’s requirement intended to replace the Diablo Canyon Power Plant (“DCPP”). The Daggett solar project is represented in the 8 MMT RDT as incremental capacity; please refer to row 2 of the unique_contracts tab in MCE’s RDT.
• Strauss Wind Energy, LLC
Strauss Wind Energy, LLC is a new build 93 MW wind project located in Alameda County. The project achieved COD on December 20, 2023, and MCE intends to apply this resource toward its procurement requirements under D.21-06-035. The Strauss Wind project is represented in the 8 MMT RDT as incremental capacity; please refer to row 3 of the unique_contracts tab in MCE’s RDT.
ii. Plans for resources that are currently non-candidate in CPUC’s IRPs not described above Open Season RFO
After counting the above-mentioned resources totaling 548.8 MW of NQC under contract, MCE is on track to meet or exceed its assigned 332 MW of NQC capacity requirement identified in D.21-06-035 and 122 MW of NQC identified in D.23-02-040. To fill current and future open positions, MCE issues annual Open Season RFOs, which seek to fill approximately 350 GWh of annual energy needs, including any incremental procurement that will be needed to fill the remaining needs under D.26-02-057. These RFOs request offers for Portfolio Content Category 1 Renewable Energy and stand-alone, front-of-the-meter energy storage. 60 MCE expects to count projects selected in future RFOs towards any future Commission-directed incremental capacity obligations. While MCE does not anticipate that the new projects will be needed for MCE’s share of capacity requirements identified in D.21-06-035 and D.23-02-040, they may serve as backup if any of the projects identified above are unsuccessful. Asthese resources are expected/planned and not currently contracted for, they are reflected as “review,” “PlannedExisting,” and “PlannedNew” resources in MCE’s RDT.

Out-of-state wind
MCE’s PCP includes 545 MW of planned new, out-of-state wind (“OOS”), with deliveries commencing in 2030 and building up through 2045. MCE has reviewed wind projects that have been offered in recent solicitations and understands that the transmission projects needed to connect OOS Wind to the CAISO grid require significant lead times. OOS wind opportunities rely on existing firm transmission routes into the CAISO or construction of new transmission with the appropriate level of import allocations and deliverability assurances for California LSEs.

Absence of such assurances make it difficult for MCE to realize the significant potential for wind located in Idaho, Wyoming, Arizona and New Mexico. Given the fact that OOS Wind is not needed until 2030, MCE believes that a careful and considered approach to potential OOS Wind projects is best. MCE will continue to monitor opportunities to purchase such resources and will evaluate offers it receives during its annual open season process. iii. Other renewable energy not described above
MCE has a 100MW existing geothermal contract expected to start delivery on January 1, 2027 and a new 38MW wind project with a COD of January 1, 2028. iv. Other energy storage not described above
MCE is not actively planning any additional energy storage investments beyond what is described above.
v. Other demand response not described above
MCE’s demand response and demand-side management efforts are described in Section III.b). vi. Other energy efficiency not described above
MCE is an administrator of California’s ratepayer-funded energy efficiency (EE) programs alongside IOUs and Regional Energy Networks (RENs). Ratepayer funding is derived through collection of the Public Purpose Program (PPP) charge from all electric service customers and is administered by the Commission. MCE currently administers programs in multifamily, single 61 family, commercial, agriculture, and industrial sectors and has received Commission funding approval for EE programs to be administered through 2027. Portfolio performance is evaluated through multiple CPUC metrics, including Total System Benefit (TSB) and cost-effectiveness measures such as the Total Resource Cost (TRC) test.

Beginning with the 2024 program year, the CPUC transitioned from separate energy and peak demand savings goals, such as kilowatt-hour, kilowatt, and therm savings, to TSB as the single goals metric for energy efficiency portfolios. The CPUC adopted this approach because first-year savings alone do not fully capture the value of energy efficiency, including lifecycle savings, hourly and seasonal grid value, greenhouse gas reductions, capacity benefits, and the long-term value of measures. TSB expresses these benefits in dollar terms and is intended to encourage portfolio administrators to pursue savings that deliver higher system value.

TRC remains an important companion metric as it measures whether the benefits of energy efficiency exceed the costs from a total resource perspective. For IOU and CCA portfolio administrators, including MCE, the CPUC requires the resource acquisition segment of the portfolio to demonstrate forecast cost-effectiveness using the TRC test, excluding Codes and Standards. As a result, MCE’s portfolio must be understood through both lenses: TSB shows the forecasted system value delivered by the portfolio, while TRC demonstrates whether the resource acquisition portion of the portfolio is cost-effective.

MCE forecasts Total System Benefit of approximately $21.7 million in 2026 and $23.7 million in 2027 under the current 2024–2027 portfolio cycle. Beginning in 2028, the forecast reflects the next energy efficiency application cycle for program years 2028–2035. The decrease from 2027 to 2028 therefore reflects a new application and planning cycle, updated assumptions, and refreshed portfolio forecasts rather than a simple year-over-year decline in portfolio performance. From 2028 through 2035, MCE’s forecasted TSB increases annually, indicating continued growth in the expected system value of MCE’s energy efficiency portfolio.
62 Figure 5: Total System Benefit of MCE's EE portfolio (2026-2035) Figure 6: TRC ratio of MCE's EE portfolio (2026 - 2035) 63 • Multifamily Strategic Energy Management Program
The Multifamily Strategic Energy Management (“MF SEM”) program serves multifamily property-management companies and their residents with a goal of achieving low-cost and no-cost energy savings that are sustained through behavioral and operational changes and the adoption of best practices. MF SEM uses a holistic, whole-property approach that employs a Normalized Meter Energy Consumption (“NMEC”) methodology and dynamic baseline models to determine eligible energy savings from all program activity at the property. MF SEM moves the energy-management conversation beyond traditional capital-equipment upgrades by focusing on internal processes, systems, and policies that can be improved to save energy.

Savings are realized year-over-year as participating organizations develop more knowledge in a culture of continuous improvement.

The program serves properties by identifying and implementing energy-saving upgrades that would not have been possible without the program’s support. Participating properties progress through a series of facilitated workshops that teach participants skills like how to map energy usage across their respective properties and develop a list of the most promising opportunities for energy savings. Savings estimates and customer incentives for operations and maintenance (“O&M”), retro-commissioning (“RCx”), and behavioral measures are calculated using pre- and post-project interval meter data.

The program addresses market barriers by providing:

Ø Customized technical assistance to overcome challenges associated with the diversity of building types, ownership types, and billing configurations, and to help with analyzing potential upgrade measures.

Ø Property management and tenant engagement.

Ø Energy-tracking models.

Ø Assessments of low-cost/no-cost, behavioral, O&M, and capital opportunities throughout the property.

Ø A range of participation options to best meet the current needs and abilities of properties.

As of January 2026, MCE has provided 5,300 multifamily units energy efficiency improvement, with 328 units receiving no-cost electrification measures through this program. The program saved 196,000 kWh and 1,900 therms.

Looking forward, the program will focus on serving existing program participants in their energy-efficiency efforts with a planned closure at the end of 2027. As the MCE program 64 sunsets, the focus will be on connecting customers to other programs and maintaining a positive relationship with MCE.
• Energy Management Program
The MCE Energy Management Program is a comprehensive program designed for agricultural, industrial, and commercial customers within MCE’s service area. The program is designed to provide individualized services to identify energy efficiency opportunities, develop and evaluate implementation options, and provide incentives in the form of technical assistance, money-back rebates, and financing.

MCE employs multiple participation pathways, leaning heavily on Strategic Energy Management as a primary strategy for engaging customers, while also offering the opportunity to pursue deemed rebates and custom projects to realize energy efficiency and cost-effectiveness goals.

The Energy Management Program includes the following objectives:

Ø Improve education and knowledge about energy use and associated economic and environmental impacts in the agricultural and industrial sectors within MCE’s service area.

Ø Provide customers with a single point of contact (“SPOC”) for their energy journey, while also connecting them to other available local and regional offerings.

Ø Ensure program impacts are verifiable and defensible, and that incentive payments align with realized savings where feasible.

As of 2026, the Energy Management program has 28 active customers in the SEM sub-program, spanning from large industrial sites to commercial office buildings. The program anticipates some of the largest natural gas savings projects to be completed, upward of 900,000 therms. In addition, there are planned projects for LED lighting, furnace retrofits, refrigeration and commercial-scale heat pump water heaters.
• Flex Market
MCE's Commercial and Residential Efficiency Market Programs provide energy efficiency incentives directly to project developers or contractors known as aggregators. The incentives are based on metered energy savings, instead of traditional energy efficiency programs, which utilize deemed or custom models. As a result, these programs do not limit the technology or energy saving strategies implemented, resulting in the opportunity to maximize energy efficiency and load-shifting projects.

As the incentive is paid directly to the aggregator, the value is passed along to the customer in the way that best drives the success of the project, either by buying down upfront costs or being paid out based on site performance.
65 In 2025, the Commercial Flex Market program primarily delivered lighting and HVAC energy management system controls projects, which yielded:

Ø 21 projects, with four additional projects to be completed in 2026.

Ø 5 participating project aggregators.

Ø Annual savings of 523,000 kWh.

Ø Annual TSB of $81,021.

MCE applied to the CPUC for approval of its 2028-2031 EE Portfolio Plan, which includes a goal of achieving 65 completed commercial projects per year.

The Residential Flex Market program delivered exclusively heat pump water heating projects in 2025, which yielded the following metrics:

Ø 21 projects throughout MCE’s four county service area.

Ø 6 participating aggregators submitted projects.

Ø Annual savings of 2,992 therms.

MCE aims to install EE equipment in approximately 200 single-family homes per year through the Residential Flex Market program throughout the next program cycle of 2028-2031, • Small Business Energy Advantage
The Small Business Energy Advantage (SBEA) program serves MCE’s small and medium businesses located in Disadvantaged Communities and low-income neighborhoods with the goal of delivering meaningful bill savings, energy-efficiency education, and other non-energy benefits. SBEA participants receive site assessments, select energy-saving upgrades, and are assigned installers to complete no cost and reduced-cost projects. SBEA partners with local community-based organizations (CBOs) and Green Business Programs (GBPs) to further outreach efforts and ensure equitable access to program resources.

Program goals are to:

Ø Provide sustained energy efficiency benefits, including those focused during the summer peak period of 4-9pm June – September.

Ø Improve equitable access to program services through local engagement by building an Outreach Network Team (ONT) made up of CBOs and GBPs.

Ø Deliver meaningful energy savings and bill savings.

Ø Focus on delivering Non-Energy Benefits (NEBs) such as improved health, comfort, and safety.

Ø Fill gaps in services that are not currently provided by other MCE programs.

In 2025, SBEA completed 167 energy efficiency projects at 165 small businesses, resulting in estimated bill savings of $82,500 per year across all participants. Of the projects completed, 137 66 were participants located in low-income census tracts, 54 were in DACs, and 133 were businesses that qualified as Hard-to-Reach (HTR).19
The program aims to build on this momentum by further investing in a community-driven approach to outreach and engagement
The program goals for 2026 are:

Ø Conduct two door-to-door community campaign events.

Ø Onboard one to two CBOs.

Ø Enroll 140 small businesses to receive energy-saving upgrades.

Ø Educate 204 customers with tips and tricks to further save energy.

MCE aims to install EE equipment in 500 qualifying small businesses in the program period 2028-2031. MCE has a long-term goal of ensuring that greater than 50 percent of the approximately 20,000 small businesses in the program’s service area have been engaged and offered EE upgrades.
vii. Other distributed generation not described above
• Energy Storage
MCE’s Energy Storage Program, launched in 2020, provides rebates, monthly bill credits and financing to support residential and non-residential customers to install battery energy storage systems paired with solar, in exchange for allowing MCE to discharge the battery daily from 4- 9pm to manage peak loads and mitigate high energy costs. Non-residential customers may also qualify for annual performance-based payments.

Since launching its Energy Storage program, MCE has supported the installation of nearly 3 MWh of batteries across 90 commercial and residential projects. Funding for the program included a $750,000 grant from the Marin Community Foundation, more than $1 million in direct MCE program incentives to reduce customer out-of-pocket costs, and over $1 million in incentives from the CPUC’s Self-Generation Incentive Program (SGIP).

Although the program is closed to new enrollments, MCE has completed recruitment of new critical facilities, pending funding from the Department of Energy (DOE) by 2028. 19 The CPUC developed specific criteria to qualify customers as Hard-to-Reach as defined in Resolution G-3497. https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M143/K573/143573160.PDF. 67 • Solar Storage Credit
MCE offers customers with solar and storage at their home a monthly bill credit ($10-$20) in exchange for automating battery discharge down to a 20% reserve margin daily from 4-9 PM.

As of January 2026, there are 1,560 customers enrolled in the credit program, with a goal of enrolling 2447 residential customers by the end of 2026. MCE is currently evaluating how MCE will continue this program, pending funding from the CPUC. viii. Transportation electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR)
• EV Charging
MCE’s EV Charging program provides EV charging station rebates, with bonus incentives for stations connected to 100% renewable energy service, free technical assistance to support the property manager, and tenant education and engagement to speed up EV adoption.

The program offers:

Ø Up to $4,500 per networked Level 2 charging port
Ø Up to $2500 per networked Level 1 or Level 2 charging outlet Ø An additional $500 per port for projects located in a designated priority population per CES 4.0 and publicly accessible
Ø Expanding EV charging access for residents of affordable multifamily housing in Marin County by installing free EV charging stations through a Marin Community Foundation grant.

Ø Support to align and combine with other EV charging incentives As of January 2026, the EV Charging program has installed 1,400 new charging ports at 142 locations, with the goal of installing 300 additional ports by April 2027. • EV Instant Rebates
MCE’s EV Instant Rebate program lowers the cost of purchasing or leasing EVs for income-qualified customers. The program offers up to $3,500 in savings ($3,500 for new and $2,000 for used) on the purchase or lease of an EV at participating dealerships. MCE’s EV Instant Rebate can be combined with other available incentives to maximize savings, depending on vehicle and customer eligibility.

As of January 2026, the EV Instant Rebate program has helped 2,388 low-income customers purchase or lease an EV, with the goal of helping a total of 876 participants by April 2027.

To ensure that the rebates are used to serve the most in-need customers, MCE is working to strengthen the income verification process. This will include mandatory quarterly income 68 verification for a percentage of program participants and rebate claw backs for customers who don’t meet requirements.
• Bidirectional Vehicle Tariff Pilot
MCE’s Bidirectional Vehicle tariff is a three-year pilot, launched in 2025, that provides customers a credit for energy exported from a compatible EV to their property (Vehicle-to-Home) or directly to the grid (Vehicle-to-Grid) during peak time periods of the day. As a pilot, MCE reserves the right to limit the number of customers enrolled in the tariff.

This technology is still in an early phase of development and is not yet commercially available to most customers. MCE is actively tracking the availability and adoption of this technology to determine when it makes sense to invest in the data collection tools needed to implement this tariff.

The pilot tariff offers the following incentives:

Ø 2025 Incentive Rates
o Summer: $0.26/kWh
o Winter: $0.20/kWh
Ø Maximum Monthly Bill Credits
o Residential: $70 ($90 if located in a state-designated disadvantaged community) o Commercial: $300 ($400 if located in a state-designated disadvantaged community)
ix. Building electrification, including any investments above and beyond what is included in Integrated Energy Policy Report (IEPR)
• Green Workforce Pathways
MCE’s Green Workforce Pathways (GWP) program supports the development of the residential energy-efficiency and electrification workforce by enhancing the skills of the existing contractor workforce and creating pathways for job seekers into sustainable, long-term careers in building electrification. For contractors, MCE offers funding to attend industry training opportunities as well as connections to vetted job seekers. For job seekers, MCE creates pathways into sustainable, long-term careers.

The GWP program provides technical support in electrification and home performance to residential contractors, as well as access to industry-focused educational opportunities for new and existing staff. GWP also provides individualized wraparound support services for job 69 seekers, including interview and resume skills, as well as sourcing and matching job seekers with local residential energy efficiency and electrification contractors.

The program is designed to leverage industry and stakeholder expertise to provide long-term, relevant training opportunities for the existing energy efficiency and electrification contractor workforce, as well as sustainable, long-term career on-ramping opportunities for job seekers.

As of January 2026, the GWP program has enrolled 11 local contractors to provide on-the-job experience to local job seekers. MCE provided supportive job placement services for 190 trainees and 50% of trainees placed with local contractors were hired into permanent jobs.

Looking ahead, MCE will continue:

Ø Leveraging relationships with residential decarbonization programs, industry trade groups, and trade ally memberships to promote regional workforce development in residential energy efficiency and decarbonization.

Ø Strengthening the pipeline for jobseeker-to-contractor matchmaking throughout all MCE service area counties.

Ø Targeting outreach to electrification contractors in MCE’s service area.

Ø Providing stipends to contractors and their staff to participate in approved industry-led electrification training.

Ø Offering Career Readiness Workshops and soft skills training to job seekers in partnership with workforce development agencies and their trainees, as well as program participants.
• Home Energy Savings
MCE’s single-family direct-install Home Energy Savings (HES) Program focuses on improving home efficiency, making homes building-electrification-ready, and installing electrification technologies. The program provides no-cost energy-saving gifts, home assessments, and home upgrades to eligible single-family homeowners and renters in MCE’s service area. As a result, the program delivers energy savings, improves comfort, enhances indoor air quality, and contributes to the reduction of greenhouse gas emissions.

The HES program targets customers in DACs whose household income falls between 200% and 400% of the Federal Poverty Guidelines, but who are still income-constrained (moderate income) and unable to participate in shared-cost market-rate programs.

The program goals are to:

Ø Provide comprehensive home upgrades to improve the efficiency of low- to moderate-income single-family homes.

Ø Increase knowledge about energy use and associated economic and environmental impacts in the residential sector within MCE’s service area. 70 Ø Serve customers via a SPOC for the customers’ energy journey, while also connecting them to other available local and regional offerings.

Ø Ensure program measures and the delivery model meet customer needs, produce health, safety, and comfort benefits, and achieve forecasted savings targets.

MCE has provided energy efficiency or electrification upgrades to 2,105 single family homes from 2019 to 2025.

Looking ahead, MCE plans to maintain the Home Energy Savings Program as a comprehensive home upgrade offering. The program will continue to target moderate-income single-family customers, while serving all low- to moderate-income residents who qualify and build greater trust with these customers. The program will continue to focus on improving home energy efficiency, with an emphasis on electrification-readiness and ways to increase its electrification offerings.

• Multifamily Energy Savings
The Multifamily Energy Savings Program (MFES) delivers energy-efficiency and electrification improvements to affordable multifamily properties within MCE’s service area. MFES provides no-cost technical assistance and rebates to property owners and tenants to support the adoption of comprehensive high-efficiency electrification and energy-efficiency measures. The program supports efforts to decarbonize and increase energy efficiency in existing affordable multifamily buildings, particularly those that have been traditionally underserved by energy-efficiency programs.

The program addresses key market barriers by:

Ø Providing customized technical assistance to navigate challenges related to diverse building types, ownership structures, and billing configurations Ø Educating property owners on participation options tailored to their property’s needs and guiding them through potential upgrade opportunities Ø Bridging funding gaps to support equitable whole-building improvements, even when certain units or measures do not qualify for other incentive programs Through flexible incentives and comprehensive support, MFES empowers property owners to implement meaningful improvements that enhance comfort, reduce utility costs, and promote long-term sustainability.

Despite MFES’ successes, building electrification—a key component of California’s decarbonization strategy—remains out of reach for many multifamily properties in MCE’s 71 service area. To help close this gap, MCE launched the MFES Resource Program in 2026 to expand access to electrification incentives, financial support, and technical assistance beyond deed-restricted properties. MCE aims to install electrification measures in up to 120 units across 1-3 properties in the 2028-2031 program period; MCE aims to install electrification measures in up to 1,200 units across 10-30 properties.

MCE is also increasing incentive levels for cost-effective electrification measures. The MFES team will continue to leverage partnerships with BayREN and others to connect shared customers with the program offerings that best maximize benefits for tenants and property owners. MCE will also continue to support commercialization of new high-efficiency technologies and making the technologies accessible to affordable multifamily communities. • Electrification Incentives
MCE offers rebates to contractors for each energy-efficient heat pump water heater (HPWH) unit they install in the home of an MCE market-rate, low/moderate income homes and multifamily properties. This can be combined with other energy efficiency rebates to further reduce customer and contractor costs. As of January 2026, the program has supported the installation of over 700 electrification and electrification readiness measures, e.g. electrical circuitry, heat pump HVACs and heat pump water heaters, with the goal to install additional 685 additional measures by April 2027.
x. Potential Centralized Procurement, pursuant to AB-1373 MCE’s PCP does not account for centralized procurement at this time. Should the Department of Water Resources (DWR) be successful in conducting centralized procurement of long-lead-time resources as set forth in D.24-08-064, MCE will commensurately adjust its procurement and planning strategy. MCE maintains its preference to conduct its own procurement per MCE’s needs and load projections to build a robust and diverse portfolio. n) Disadvantaged Communities
• Green Access Program
MCE’s Green Access Program offerings are described in Section III.d.ii. 72 • Sustainable Workforce and Diversity Policy
In 2017, MCE’s Board approved a Sustainable Workforce and Diversity Policy20 to facilitate and encourage diversity and a sustainable workforce through its support for the following:

Ø Fair compensation in direct hiring, renewable development projects, customer programs, and procurement services.

Ø Development of locally generated renewable energy within the MCE service area.

Ø Direct use of union members from multiple trades.

Ø Quality training, apprenticeship, and pre-apprenticeship programs.

Ø Direct use of local businesses in MCE’s service area.

Ø Development of California-based job opportunities.

Ø Business and workforce initiatives located in low-income and disadvantaged communities.

Ø Direct use of Disabled Veteran-owned Business Enterprises (“DVBE”) and LGBT-owned Business Enterprises (“LGBTBE”).

Ø Direct use of green and sustainable businesses.

Ø Use of direct hiring practices that promote diversity in the workplace.

MCE submits an annual Supplier Diversity Report21 to the CPUC every March that outlines our voluntary work. MCE’s supplier diversity efforts help businesses whose owners are women, minority, LGBTQ, and/or disabled veterans to access opportunities in California’s energy sector.

By leading our supplier diversity workshops and training sessions over several years, MCE has helped many businesses receive certification in the state’s Supplier Diversity Clearing house to access utility contracts and more easily grow their local businesses.

In 2022, MCE adopted Sustainable Workforce Guidelines22 to create a more detailed plan for implementing its Sustainable Workforce and Diversity Policy, further demonstrating its commitment to procuring resources that benefit our customers, our planet, and our future.

These guidelines outline how MCE integrates these priorities into PPAs with third parties, MCE-owned or MCE-led power generation projects, and MCE customer programs, services, supplies, and direct hiring. For example:

Ø When possible, MCE shall give preference to projects within MCE’s service area and to CBOs and local associations serving disadvantaged and low-income communities. 20 See MCE November 16, 2017, Board of Directors Meeting Packet, Agenda Item No. 7 Attachment A https://www.mcecleanenergy.org/wp-content/uploads/2020/05/MCE-Board-Meeting-Packet-November_2017.pdf 21 See https://mcecleanenergy.org/wp-content/uploads/2025/03/2025_MCE_Supplier-Diversity-Report.pdf. 22 See https://www.mcecleanenergy.org/wp-content/uploads/2022/05/MCE-Sustainable-Workforce-Guidelines_05122022.pdf. 73 Ø MCE has three tiers of requirements for union labor depending on the location of proposed projects. Projects located in Contra Costa County and over 1 MW in size must adhere to the terms of the Project Labor Agreement (“PLA”) between MCE and International Brotherhood of Electrical Workers (“IBEW”) Local 302 (“MCE/IBEW PLA”).

Projects within Napa, Marin, or Solano County must participate in a PLA of similar scope and requirements with participating unions for workforce hired as described in the MCE/IBEW PLA. Projects outside of MCE’s service area are encouraged to enter into project labor agreements of similar scope and requirements with participating unions for workforce as described in the MCE/IBEW PLA.

Ø For projects located in MCE’s service area, 50% of work hours are required to come from permanent residents who reside within the same county as the project.

Ø MCE will not accept any proposals for projects that rely on equipment or resources built with forced labor. MCE adopted this prohibition two years ahead of federal law, signed by President Biden in June 2022.

Ø Any renewable development project that is developed or owned by MCE qualifies as a public works project and requires prevailing wages to be paid.

These efforts have resulted in significant local developments. To date, MCE has helped build over 46 MW of new renewable projects in our service area. All local projects over 1 MW were built with union labor. In 2025, MCE spent more than $19 million on small, local, and diverse businesses.

MCE also offers the DAC-GT program, as described above, that provides qualifying customers living in CalEnviroScreen-designated DACs access to 100% renewable energy and a 20% discount on their electricity bills for up to 20 years. The program is supported by the development of new clean resources. In developing its IRP, MCE carefully considered the impact of its resource procurement on DACs. MCE’s PCP minimizes the use of fossil-based resources and unspecified system power over the planning horizon, reducing reliance on natural gas generators that have historically harmed DACs. • Ad Hoc Workforce Development
Through its mission, MCE strives to grow the green economy, support local contractors, and provide equitable access to workforce development opportunities. In addition to the Green Workforce Pathways program, MCE led a $380,000 grant in partnership with the Marin Community Foundation and the LIME Foundation to train youth in Marin County for green careers through the NextGen Trades Academy. MCE continues to explore future opportunities for workforce development in its service area.
74 • Strategic Recruiting and Hiring Practices
MCE’s recruiting and hiring practices include targeted job postings, partnerships with community-based organizations (CBOs), education and employment organizations, physical attendance at job recruitment fairs, and the creation of diverse cross-departmental hiring panels. Some MCE jobs may substitute direct work experience for education requirements.

MCE has also tailored employee benefit packages to be more inclusive and to apply to a broad range of people.

Equity is at the core of MCE’s decision-making as it pertains to employment practices and decisions. Demonstrating its values, MCE’s Human Resources team consistently conducts internal and external equity analyses pertaining to the agency’s compensation-setting, promoting, and hiring best practices.

MCE also supports creating equitable job and economic development opportunities for members of MCE Communities. MCE offers paid internships for community members who may not otherwise have the opportunity to work in the renewable energy industry. In the internships, community members have the opportunities to work on meaningful projects, learn more about the renewable energy industry, and contribute to furthering MCE’s mission. • Community Power Coalition
MCE’s Community Power Coalition23 is a network of nearly 170 community-based organizations (CBOs) who advise MCE on areas including environmental, social, and racial justice issues as they intersect with the work of delivering renewable energy to MCE communities. These organizations also help MCE raise awareness and reach more customers. MCE’s recruitment for the Coalition prioritizes organizations that:

Ø Expand awareness and access to affordable renewable services.

Ø Accelerate the transition to a clean energy future through workforce development training opportunities.

Ø Develop inclusive programs and policies at MCE.

Ø Identify just and equitable community collaboration opportunities aligned with MCE’s environmental justice values.

MCE’s Community Power Coalition offers expert advice on the needs of their constituents, including how MCE can best support underserved customers and environmental equity through its programs, policies, and procurement.
23 See https://mcecleanenergy.org/climate-justice/#_communitypower. 75 o) LSEs’ Tribal Customers
MCE’s service area does not include service to any specific tribes or tribal customers. However, regarding unceded territories, MCE’s service area sits in the territory of the Miwok (Coast Miwok and Bay Miwok), Ohlone (including Lisjan, Karkin, Muwekma) and Wintun People (South Patwin). MCE works to educate itself on indigenous communities and indigenous-serving organizations within its service area.
p) Procurement Products
MCE intends to utilize the physical energy products in procurement activities associated with its PCP as summarized in Table 13. Contracts are expected to be conducted bilaterally rather than via commodities exchanges. Individual contracts may be used to procure one or more of the following physical energy products (e.g., full-toll agreements).

Table 13: Summary of procurement products MCE intends to use Product Description
Physical energy, RPS qualifying Renewable energy qualified to meet California RPS (preference for PCC1)
Physical energy, other carbon free Non-carbon emitting energy that does not meet California RPS; e.g., large hydro, ACS
Physical energy, CAISO energy Energy delivered to the CAISO grid from unspecified sources
Capacity, Net Qualifying Capacity Capacity qualified to meet RA program standards
q) Commission Direction of Actions
MCE is not seeking any specific direction of actions from the Commission at this time. However, MCE notes that it is tracking and participating in the Commission’s efforts to implement a new procurement program, the Reliable Clean Power Procurement Program (“RCPPP”). MCE looks forward to continued exploration of options for a programmatic approach toward procurement to meet IRP process goals. Whichever programmatic approach the Commission ultimately adopts, it is critical that the Commission ensure any new program equitably reflects an LSE’s full contribution to system reliability, accurately determines and fairly allocates procurement need, 76 achieves California’s environmental goals, and allows for flexibility to accommodate continuously evolving grid needs.

For example, the statewide load forecasts project substantial demand growth over the planning horizon, driven in large part by projected data center development that may or may not materialize. MCE encourages the Commission to work closely with the CEC and all LSEs to reduce the risk of costly over procurement for California ratepayers. MCE further encourages the Commission to allocate any reliability need associated with such load growth equitably and in accordance with cost-causation principles. Theories that such load is beneficial and can lower rates for all customers is largely unproven, and customers across the state should not be required to subsidize the reliability needs of data centers located outside of their service areas.

V. Lessons Learned
MCE shares the Commission’s commitment to robust and comprehensive integrated resource planning. MCE understands the significant procedural complexity that defines the Commission’s IRP development. Accordingly, this complexity extends to individual LSEs as they implement statutory and regulatory requirements into their resource planning efforts. In addition to the statutory requirements articulated in 454.52(a)(1)(A) -(I), MCE’s resource planning process must also give deference to its Board of Directors, which is granted statutory authority to govern MCE’s procurement and approve MCE’s IRP under 454.52(b)(3) and 366.2(a)(5).

To meet all the aforementioned statutory objectives and requirements, it is critical for MCE and other similarly situated LSEs to receive clear and timely guidance from the Commission, along with adequate time to incorporate this guidance into its planning process. MCE appreciates the Commission taking steps in this IRP cycle to adhere firmly to its timelines and reduce the number of template updates. MCE encourages the Commission to continue this work aiding all stakeholders in meeting statutory requirements, as well as comprehensively and thoroughly addressing the state’s resource planning efforts.

VI. Glossary of Terms
Alternative Portfolio: LSEs are permitted to submit “Alternative Portfolios” developed from scenarios using different assumptions from those used in the Preferred System Plan with updates. Any deviations from the “Conforming Portfolio” must be explained and justified.

Approve (Plan): the CPUC’s obligation to approve an LSE’s integrated resource plan derives from Public Utilities Code Section 454.52(b)(2) and the procurement planning process described 77 in Public Utilities Code Section 454.5, in addition to the CPUC obligation to ensure safe and reliable service at just and reasonable rates under Public Utilities Code Section 451.

Balancing Authority Area (CAISO): the collection of generation, transmission, and loads within the metered boundaries of the Balancing Authority. The Balancing Authority maintains load-resource balance within this area.

Baseline resources: Those resources assumed to be fixed as a capacity expansion model input, as opposed to Candidate resources, which are selected by the model and are incremental to the Baseline. Baseline resources are existing (already online) or owned or contracted to come online within the planning horizon. Existing resources with announced retirements are excluded from the Baseline for the applicable years. Being “contracted” refers to a resource holding signed contract/s with an LSE/s for much of its energy and capacity, as applicable, for a significant portion of its useful life. The contracts refer to those approved by the CPUC and/or the LSE’s governing board, as applicable. These criteria indicate the resource is relatively certain to come online. Baseline resources that are not online at the time of modeling may have a failure rate applied to their nameplate capacity to allow for the risk of them failing to come online.

Candidate resource: those resources, such as renewables, energy storage, natural gas generation, and demand response, available for selection in IRP capacity expansion modeling, incremental to the Baseline resources.

Capacity Expansion Model: a capacity expansion model is a computer model that simulates generation and transmission investment to meet forecast electric load over many years, usually with the objective of minimizing the total cost of owning and operating the electrical system.

Capacity expansion models can also be configured to only allow solutions that meet specific requirements, such as providing a minimum amount of capacity to ensure the reliability of the system or maintaining greenhouse gas emissions below an established level.

Certify (a Community Choice Aggregator Plan): Public Utilities Code 454.52(b)(3) requires the CPUC to certify the integrated resource plans of CCAs. “Certify” requires a formal act of the Commission to determine that the CCA’s Plan complies with the requirements of the statute and the process established via Public Utilities Code 454.51(a). In addition, the Commission must review the CCA Plans to determine any potential impacts on public utility bundled customers under Public Utilities Code Sections 451 and 454, among others.

Clean System Power (CSP) methodology: the methodology used to estimate GHG, and criteria pollutant emissions associated with an LSE’s Portfolio based on how the LSE will expect to rely on system power on an hourly basis.

Community Choice Aggregator: a governmental entity formed by a city or county to procure electricity for its residents, businesses, and municipal facilities. 78 Conforming Portfolio: the LSE portfolio that conforms to IRP Planning Standards, the 2030 LSE-specific GHG Emissions Benchmark, use of the LSE’s assigned load forecast, use of inputs and assumptions matching those used in developing the Reference System Portfolio, as well as other IRP requirements including the filing of a complete Narrative Template, a Resource Data Template and Clean System Power Calculator.

Effective Load Carrying Capacity: a percentage that expresses how well a resource is able avoid loss-of-load events (considering availability and use limitations). The percentage is relative to a reference resource, for example a resource that is always available with no use limitations. It is calculated via probabilistic reliability modeling and yields a single percentage value for a given resource or grouping of resources.

Effective Megawatts (MW): perfect capacity equivalent MW, such as the MW calculated by applying an ELCC % multiplier to nameplate MW.

Electric Service Provider: an entity that offers electric service to a retail or end-use customer, but which does not fall within the definition of an electrical corporation under Public Utilities Code Section 218.

Filing Entity: an entity required by statute to file an integrated resource plan with CPUC.

Future: a set of assumptions about future conditions, such as load or gas prices.

GHG Benchmark (or LSE-specific 2030 GHG Benchmark): the mass-based GHG emission planning targets calculated by staff for each LSE based on the methodology established by the California Air Resources Board and required for use in LSE Portfolio development in IRP.

GHG Planning Price: the systemwide marginal GHG abatement cost associated with achieving a specific electric sector 2030 GHG planning target.

Integrated Resources Planning Standards (Planning Standards): the set of CPUC IRP rules, guidelines, formulas, and metrics that LSEs must include in their LSE Plans.

Integrated Resource Planning (IRP) process: integrated resource planning process; the repeating cycle through which integrated resource plans are prepared, submitted, and reviewed by the CPUC
Long term: more than 5 years unless otherwise specified.

Load Serving Entity: an electrical corporation, electric service provider, community choice aggregator, or electric cooperative.

Load Serving Entity (LSE) Plan: an LSE’s integrated resource plan; the full set of documents and information submitted by an LSE to the CPUC as part of the IRP process.

Load Serving Entity (LSE) Portfolio: a set of supply- and/or demand-side resources with certain attributes that together serve the LSE’s assigned load over the IRP planning horizon.

Loss of Load Expectation (LOLE): a metric that quantifies the expected frequency of loss-of-load events per year. Loss-of-load is any instance where available generating capacity is insufficient to serve electric demand. If one or more instances of loss-of-load occurring within the same 79 day regardless of duration are counted as one loss-of-load event, then the LOLE metric can be compared to a reference point such as the industry probabilistic reliability standard of “one expected day in 10 years,” i.e., a LOLE of 0.1.

Maximum Import Capability: a California ISO metric that represents a quantity in MWs of imports determined by the CAISO to be simultaneously deliverable to the aggregate of load in the ISO’s Balancing Authority (BAA) Area and thus eligible for use in the RA process. The California ISO assess a MIC MW value for each intertie into the ISO’s BAA and allocated yearly to the LSEs. A LSE’s RA import showings are limited to its share of the MIC at each intertie.

Net Qualifying Capacity (NQC): Qualifying Capacity reduced, as applicable, based on: (1) testing and verification; (2) application of performance criteria; and (3) deliverability restrictions. The Net Qualifying Capacity determination shall be made by the California ISO pursuant to the provisions of this California ISO Tariff and the applicable Business Practice Manual.

Non-modeled costs: embedded fixed costs in today’s energy system (e.g., existing distribution revenue requirement, existing transmission revenue requirement, and energy efficiency program cost).

Nonstandard LSE Plan: type of integrated resource plan that an LSE may be eligible to file if it serves load outside the CAISO balancing authority area.

Optimization: an exercise undertaken in the CPUC’s Integrated Resource Planning (IRP) process using a capacity expansion model to identify a least-cost portfolio of electricity resources for meeting specific policy constraints, such as GHG reduction or RPS targets, while maintaining reliability given a set of assumptions about the future. Optimization in IRP considers resources assumed to be online over the planning horizon (baseline resources), some of which the model may choose not to retain, and additional resources (candidate resources) that the model is able to select to meet future grid needs.

Planned resource: any resource included in an LSE portfolio, whether already online or not, that is yet to be procured. Relating this to capacity expansion modeling terms, planned resources can be baseline resources (needing contract renewal, or currently owned/contracted by another LSE), candidate resources, or possibly resources that were not considered by the modeling, e.g., due to the passage of time between the modeling taking place and LSEs developing their plans. Planned resources can be specific (e.g., with a CAISO ID) or generic, with only the type, size and some geographic information identified.

Qualifying capacity: the maximum amount of Resource Adequacy Benefits a generating facility could provide before an assessment of its net qualifying capacity.

Preferred Conforming Portfolio: the conforming portfolio preferred by an LSE as the most suitable to its own needs; submitted to CPUC for review as one element of the LSE’s overall IRP plan.
80 Preferred System Plan: The Commission’s integrated resource plan composed of both the aggregation of LSE portfolios (i.e., Preferred System Portfolio) and the set of actions necessary to implement that portfolio (i.e., Preferred System Action Plan).

Preferred System Portfolio: the combined portfolios of individual LSEs within the CAISO, aggregated, reviewed, and possibly modified by Commission staff as a proposal to the Commission, and adopted by the Commission as most responsive to statutory requirements per Pub. Util. Code 454.51; part of the Preferred System Plan.

Short term: 1 to 3 years (unless otherwise specified).

Staff: CPUC Energy Division staff (unless otherwise specified).

Standard LSE Plan: type of integrated resource plan that an LSE is required to file if it serves load within the CAISO balancing authority area (unless the LSE demonstrates exemption from the IRP process).

Transmission Planning Process (TPP): annual process conducted by the California Independent System Operator (CAISO) to identify potential transmission system limitations and areas that need reinforcements over a 10-year horizon.

July 16, 2026
TO: MCE Board of Directors
FROM: Shanelle Scales-Preston, MCE Board Chair
Cindy Darling, MCE Board Vice Chair
Barbara Coler, MCE Executive Committee Chair
RE: Proposed Creation of Ad Hoc CEO Search Committee (Agenda Item #07)
Dear Board Members:

Summary:

As you are aware, CEO Weisz left MCE on June 17, 2026. Therefore, the Board will be initiating a nationwide search for a new CEO for the agency. It is critical that the search process begin very soon, working with an Executive Search recruitment firm. The framework that has been developed by your Board Chair, Vice Chair and Executive Committee Chair is to ensure that we balance efficiency, timeliness, thoroughness, and candidate confidentiality to ensure the Board can retain a highly qualified CEO. While we have our Acting CEO in place, conducting the search, the recruitment process and subsequent interviews are time critical.

We therefore recommend creation of an Ad Hoc CEO Search Committee to lead these efforts. Of course, updates would be provided to the Board and the Executive Committee as appropriate during the process. In addition, we recommend that the Ad Hoc CEO Search Committee be authorized to request that MCE staff provide the staff or external resources the committee deems necessary to support its efforts, including an Executive Search recruitment firm (we welcome recommendations) and to work with the firm to design the recruitment and selection process, provided the final CEO candidates would be interviewed by the full Board.1 Discussions with the retained Executive Search firm would determine the fine-tuned details of the process. Being overly prescriptive about the process at this juncture will delay the search and may result in a process that lacks the benefit of input of the recruitment firm.

The Ad Hoc CEO Search Committee would work directly with the firm throughout the process. And, of course, while there may be vetting of the full candidate pool by the recruitment firm and further vetting by the Ad Hoc and/or Executive Committee, the full Board would decide the candidate to be 1 The Acting CEO has the authority of MCE’s procurement officer to approve and execute contracts with vendors for services in an amount not to exceed $400,000 per fiscal year per Resolution 2022-17. hired as CEO. All interviews would be conducted in Closed Session consistent with the Government Code to ensure confidentiality of the candidates.

Given the nature of the work, the Committee needs flexibility to meet frequently, virtually, and over email, as ad hoc committees are permitted to do under the Brown Act. We invite the Ad Hoc CEO Search Committee to leverage staff and Legal Counsel to support the committee during the process but defer to the Committee to identify and select the staffing resources it deems appropriate.

Given that the Committee will be responsible for conducting the CEO Search, it is appropriate to have Board leadership, Chair Scales-Preston and Vice Chair Darling, in addition to Executive Committee Chair Coler (Ex Com has many delegated responsibilities for the CEO) as members of the Ad Hoc Committee. To ensure that each MCE County is represented, the addition of Directors Painter (Napa) and Birdseye (Benicia) is appropriate. In addition, at the July 6 Executive Committee meeting, Directors Sackett (Marin County) and McCormick (Lafayette) were proposed to be added.

All have indicated an interest and willingness to serve on this Ad Hoc Committee. It is highly recommended that the Committee is limited to no more than seven members (not too big or too small) to ensure they can meet often without many scheduling conflicts. On July 6, the Executive Committee voted 7-2 to propose these 7 members to the Board to make up the Committee.

The Executive Committee requested that MCE staff send an email request out to all MCE Directors to inquire if others have an interest in serving on this Committee. If others express an interest the Board may consider changing the proposed composition.

Some members of the Executive Committee also requested the potential of hiring an Interim CEO be included in the scope of the Ad Hoc Committee. While some Executive Committee members were interested in first moving forward with the process of hiring an Interim CEO or an Interim COO to provide immediate relief to the Acting CEO, there was no recommendation to do so at this time.

By including this as a part of the scope of the Ad Hoc Committee, we retain the flexibility to proceed with this if necessary in the future.

The Executive Committee also requested that the Ad Hoc, once formed, develop a list of touchpoint milestones to be presented at either the Executive Committee and/or the Board (depending on timing) which may include, among others, hiring of the Executive Search firm, the position description and salary range, the process overview, and other potential key milestones. We are committed to an efficient, timely, and thorough process. It was agreed that expediency is important while ensuring the most qualified candidate is selected. To reiterate, the full Board will conduct interviews of the CEO finalists and make the decision as to the candidate to select as the new CEO.

Fiscal Impacts:

Costs will be determined through discussions with the recruitment firms. Assuming cost is less than $100,000, there are sufficient funds available in MCE’s Fiscal Year Ending 2027 Operating Budget.

Recommendations:

1. Approve the Executive Committee’s recommendation of the creation of an Ad Hoc CEO Search Committee, consisting of Directors Scales-Preston, Darling, Coler, Painter Birdseye, Sackett, and McCormick to lead the search for the new MCE CEO, provided that the Committee bring key touch points (including the selection of a recruitment firm) to the Executive Committee or the Board (based on timing of meetings), and that the final CEO candidates be brought to the full Board for interviews and for the selection of the new CEO.

2. Authorize the Ad Hoc CEO Search Committee to request that MCE staff provide the staffing and external resources the Committee deems necessary, including retaining an external Executive Search Recruitment firm.

Attachment C
MCE 2026 IRP Resource Data Template
Public Version
lse_unique_contract_id resource alternative_resource_name contract_status project_interconnection_position Daggett_Solar_Generic SISPRG_2_DS3SR2 DAGGET_7_N017,DAGGET_7_N018 Online Q-1314 Strauss_PCC1_MCE STRAUS_1_STRWD1 STRAUSSWIND Online WDT-1320 Golden_Fields_Solar_Generic RSMNDS_2_RSESR1 Online Q-1212 Cormorant_Storage_MCE _NEW_GENERIC_BATTERY_STORAGE Development Q-1552 Key_Storage_LD_MCE _NEW_GENERIC_BATTERY_STORAGE Development Q-1479 Corby_Storage_MCE _NEW_GENERIC_BATTERY_STORAGE Development Q-1270 Humboldt House_PCC1_MCE _NEW_GENERIC_GEOTHERMAL Development Geothermal_Import_Planned Allium_PCC1_MCE _NEW_GENERIC_SOLAR_1AXIS 110MW_PV_110MW_BESS_4Hr_CentralCoast Development Q-1921 Roccasecca_Storage_MCE _NEW_GENERIC_BATTERY_STORAGE StandAlone_Storage_126.5MW_4Hour_MCE_Tranche 4 Development 1347 Mulqueeney_Wind_PCC1_MCE _NEW_GENERIC_WIND_CA Wind_80MW_MCE Development 1277,1459 Desert Harvest_MCE DSRTHV_2_DH1SR1 DESERT HARVEST Online Antelope 2_MCE BGSKYN_2_AS2SR1 Online
Corcoran_MCE CORCAN_1_SOLAR2 CORCCITY_7_N002 Online
Goose Lake_MCE GOOSLK_1_SOLAR1 GOSLKPV_7_N001 Online
Great Valley_MCE TRNQL8_2_ROJSR1 TRANQUILLITY 8 ROJO Online Hay_MCE PEABDY_2_LNDFL1 G2 ENERGY HAY ROAD POWER PLANT Online Kern Tule_PCC1_1_LT_MCE KRNCNY_6_UNIT KRNCNYN_6_N001 Online Lincoln_MCE PLSNTG_7_LNCLND LINCOLN LANDFILL POWER PLANT Online Little Bear 1_MCE LTBERA_1_LB1SR1 LITTLE BEAR SOLAR 1 Online Little Bear 3_MCE LTBEAR_1_LB3SR3 LITTLE BEAR 3 SOLAR Online Little Bear 4_MCE LTBEAR_1_LB4SR4 LITTLE BEAR 4 Online
Little Bear 5_MCE LTBEAR_1_LB4SR5 LITTLE BEAR 4 SOLAR 5 Online MCE Solar 1_2.0_MCE RICHMN_1_SOLAR CHEVRON 2, RICHGEN_7_N002 Online MCE Solar 1_8.5_MCE RICHMN_1_CHVSR2 CHEVRON 8.5, RICHGN2_7_N001 Online Mustang_MCE MSTANG_2_SOLAR4 MUSTANG 4, Q643WC2_7_N003 Online Ostrom_MCE WHEATL_6_LNDFIL G2 ENERGY, OSTROM ROAD, LLC Online Geysers_MCE GEYS13_7_UNIT13 Online
Voyager II_MCE VOYAGR_2_VOYWD3 VOYAGER WIND 3, VOYAGN3_7_N001 Online Windpower_PCC1_1_LT_MCE_Update GARNET_1_WINDS RENWD_1_QF, BUCKWND_1_N001 Online Redwood Landfill_MCE NOVATO_6_LNDFL REDWOOD RENEWABLE ENERGY, RDWDLNDF_7_N001 Online Geysers_PCC1_2_LT_MCE _EXISTING_GENERIC_GEOTHERMAL Online Buena Vista_PCC1_1_MCE _NEW_GENERIC_WIND_CA WNDMSTR_2_N001 Development Buck_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
SR Airport_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Cooley I_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Cost Plus_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Freethy 1_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Freethy 2_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Cooley_DRES Quarry 2.4_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Oakley RV & Boat Storage_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Soscal Ferry Solar C_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Soscal Ferry Solar D_MCE _EXISTING_GENERIC_SOLAR_FIXED Online American Canyon Solar A_MCE _EXISTING_GENERIC_SOLAR_FIXED Online American Canyon Solar B_MCE _EXISTING_GENERIC_SOLAR_FIXED Online American Canyon Solar C_MCE _EXISTING_GENERIC_SOLAR_FIXED Online SR Airport 2_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
lse_unique_contract_id resource alternative_resource_name contract_status project_interconnection_position EO Products_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Silveira Ranch A_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Silveira Ranch B_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Silveira Ranch C_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Lake Herman_PCC1_1_LT_MCE BAHIA_2_LKHSR1 Online EXXONBH_7_N005 Byron Hot Springs_PCC1_2_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Oakley Phase 3_PCC1_1_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Byron Highway_PCC1_1_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Fallon_PCC1_1_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Napa Self Storage_PCC1_1_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online CMSA_Updated_PCC1_2_LT_MCE _EXISTING_GENERIC_BIOGAS_LANDFILLGAS Online 26SB 8me_PCC1_1_MCE _EXISTING_GENERIC_SOLAR_FIXED Online TEA_PCC1_4_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
TEA_PCC1_13_MCE _EXISTING_GENERIC_WIND Online
BP_PCC1_1_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
Townsite_PCC1_1_MCE TOWNSITE_2_MEADDYN Online
SDG&E_PCC1_1_MCE _EXISTING_GENERIC_WIND Online
ARICA_PCC1_1_MCE _EXISTING_GENERIC_SOLAR_FIXED Online
GPC_PCC1_1_LT_MCE _EXISTING_GENERIC_GEOTHERMAL Online
RESI_RA_2_NS_MCE _EXISTING_GENERIC_DR Online
Conflitti Jr_PCC1_DAC_1_LT_MCE _EXISTING_GENERIC_SOLAR_FIXED Online Conflitti_PCC1_DAC_2_LT_MCE PNOCHE_2_CEFSR1 Online
CES Electron Farm_RA_1_NS_MCE PNOCHE_2_CEFSR1 Online
WAPA_BR_2_MCE _EXISTING_GENERIC_INSTATE_LARGE_HYDRO Online SENA_CF_16_MCE _EXISTING_GENERIC_INSTATE_LARGE_HYDRO Online CONSTEL_ACS_1_MCE _EXISTING_GENERIC_NW_HYDRO Online
PG&E_Hydro_7_MCE _EXISTING_GENERIC_INSTATE_LARGE_HYDRO Online PG&E_Hydro_8_MCE_Allocation _EXISTING_GENERIC_INSTATE_LARGE_HYDRO Online PG&E_Nuke_2_MCE_Allocation _EXISTING_GENERIC_NUCLEAR Online SENA_CF_17_MCE _EXISTING_GENERIC_INSTATE_LARGE_HYDRO Online CCSF_PCC1_Sell_1_MCE CORCAN_1_SOLAR2 Online
EBCE_PCC1_Sell_2_MCE GOOSLK_1_SOLAR1 Online
CAM - DR Allocation _EXISTING_GENERIC_DR Online
CAM - Peaker Allocation _EXISTING_GENERIC_PEAKER Online CAM - Storage _EXISTING_GENERIC_BATTERY_STORAGE Online
Other CAM _EXISTING_GENERIC_COMBINED_CYCLE Online
LT Geothermal 1 _NEW_GENERIC_GEOTHERMAL PlannedNew
LT Solar 1 _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 1 _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Wind CA 1 _NEW_GENERIC_WIND_CA PlannedNew
LT Wind Out of State 1 _NEW_GENERIC_WIND_OOS_AZNM PlannedNew LT Geothermal 2 _NEW_GENERIC_GEOTHERMAL PlannedNew
LT Solar 2a _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 2a _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Solar 2b _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 2b _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Solar 2c _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 2c _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Wind CA 2 _NEW_GENERIC_WIND_CA PlannedNew
LT Solar 3a _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 3a _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Solar 3b _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 3b _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Solar 3c _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 3c _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Wind Out of State 3a _NEW_GENERIC_WIND_OOS_AZNM PlannedNew LT Wind Out of State 3b _NEW_GENERIC_WIND_OOS_WY PlannedNew LT Solar 4a _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Storage 4a _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT Solar 4b _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Solar 4c _NEW_GENERIC_SOLAR_1AXIS PlannedNew
LT Wind Out of State 4 _NEW_GENERIC_WIND_OOS_AZNM PlannedNew ST Solar _EXISTING_GENERIC_SOLAR_1AXIS PlannedExisting
ST Wind _EXISTING_GENERIC_WIND PlannedExisting
ST Large Hydro _EXISTING_GENERIC_INSTATE_LARGE_HYDRO PlannedExisting LT Storage 0 _NEW_GENERIC_BATTERY_STORAGE PlannedNew
LT LD Storage 1 _NEW_GENERIC_BATTERY_STORAGE PlannedNew GPC_PCC1_1_LT_MCE_renewal _EXISTING_GENERIC_GEOTHERMAL PlannedExisting Generic CCGT RA_2026 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2027 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting lse_unique_contract_id resource alternative_resource_name contract_status project_interconnection_position Generic CCGT RA_2028 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2029 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2030 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2031 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2032 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2033 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2034 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2035 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2036 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2037 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2038 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2039 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2040 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2041 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2042 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2043 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2044 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting Generic CCGT RA_2045 _EXISTING_GENERIC_COMBINED_CYCLE PlannedExisting lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
interconnection_substation marginal_addition marginal_addition_to total_nameplate_capacity contracted_nameplate_capacity sep_contracted_mw_nqc NA NA
110
110 12.21
NA NA

95.25 93.35 20.69
NA NA
100
100 0
250.0
250.0 250.0

35.0 35.0 35.0
100.0
100.0 100.0
Will interconnect to Thunder Mountain Switching Station in NV Energy’s North System and will be imported into CAISO at Mona

20.0 20.0 18.6
Crazy Horse Canyon-Hollister 115 kV Line Tap
110.0
110.0 110.0
Sloan Canyon Switching Station 126.6 126.6 126.6
Tesla TS 230 kV bus 80.0 80.0 19.7
Red Bluff Substation NA NAROW1_2_UNIT 80 80 11.12
SCE Antelope 220 kV 105 105 35.07
11 11 3.67
12 12 4.01
100 100 33.4
8 1.6 1.5
NA NA NAROW1_2_UNIT 10.6 10.6 0.79

4.98 4.98 3.1
Mendota Substation 40 40 5.6
Mendota Substation 20 20 2.8
Mendota Substation 50 50 6
Mendota Substation 50 50 7
PG&E’s 12.47 kV Richmond R 1129
2 2 0.66
PG&E’s 12.47 kV Richmond R 1120

8.5 8.5 2.84
30 30 10.02

3.55 3.55 3.55
NA NA 73 10 10
Windhub Substation 42.45 42 0.45
Garnet Substation

49.5 49.5 6.9

3.9 3.5 3.21
NA NA
25 7 6.496
PG&E's Buena Vista-Windmaster 230 kV line 38 38 5.586
1 1 0
0 0

0.99 0.99 0

0.99 0.99 0
0 NA NA NAROW1_2_UNIT 1 1 0

0.99 0.99 0

0.99 0.99 0
0 0
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
interconnection_substation marginal_addition marginal_addition_to total_nameplate_capacity contracted_nameplate_capacity sep_contracted_mw_nqc 0 0.99 0.99 0

0.99 0.99 0

0.99 0.99 0
PG&E’s Bahia 1104 distribution circuit NA 5 5 0
1 1 0
NA NA 1 1 0
NA NA 3 3 0
NA NA 1 1 0
NA NA 1 1 0
NA NA 1 1 0
SCE Windhub 220kV Switchyard NA 0
NA NA 0
NA NA 0
NA NA 0
0 0
Red Bluff 230 kV substation 0
100 100 100
15 15 13.41
Panoche 1102 distribution line, Panoche Substation 0.24 0.24 0 Panoche 1102 distribution line, Panoche Substation 4.4 4.4 0 Panoche 1102 distribution line, Panoche Substation 4.4 4.4 0 0 0
0 0
0 0
356.57 356.57 356.57
20 20 20
141.8871162 141.8871162 141.8871162
141.8871162 141.8871162 141.8871162

30.83853681 30.83853681 30.83853681

56.39761294 56.39761294 56.39761294
170.2413976 170.2413976 170.2413976
170.2413976 170.2413976 170.2413976
170.2413976 170.2413976 170.2413976
170.2413976 170.2413976 170.2413976
170.2413976 170.2413976 170.2413976
170.2413976 170.2413976 170.2413976
138.2631726 138.2631726 138.2631726
229.954737 229.954737 229.954737
0 0 0
229.954737 229.954737 229.954737
230 230 230
229.954737 229.954737 229.954737
230 230 230
161.4726975 161.4726975 161.4726975
161.4726975 161.4726975 161.4726975
171 171 171
171.0986931 171.0986931 171.0986931
191.2502251 191.2502251 191.2502251
0 0 0
0 0 0
0 0 0
185 185 185
25 25 25
100 100 100
469.9696238 469.9696238 469.9696238
303.9616114 303.9616114 303.9616114
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
interconnection_substation marginal_addition marginal_addition_to total_nameplate_capacity contracted_nameplate_capacity sep_contracted_mw_nqc 380.2026432 380.2026432 380.2026432
452.2560714 452.2560714 452.2560714
449.6351132 449.6351132 449.6351132
553.636549 553.636549 553.636549
582.0539046 582.0539046 582.0539046
587.3636001 587.3636001 587.3636001
579.3801455 579.3801455 579.3801455
493.3451542 493.3451542 493.3451542
450.3706931 450.3706931 450.3706931
483.7523259 483.7523259 483.7523259
509.1889201 509.1889201 509.1889201
458.9161697 458.9161697 458.9161697
356.1719829 356.1719829 356.1719829
432.6496308 432.6496308 432.6496308
577.1533331 577.1533331 577.1533331
557.5254649 557.5254649 557.5254649
599.5192435 599.5192435 599.5192435
550.5213704 550.5213704 550.5213704
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
contract_gwh_annual is_hybrid_paired can_charge_from_grid total_generator_mw contracted_generator_mw total_storage_mw contracted_storage_mw solar_technology_sub_type 331 ExistingSolarExistingStorage 110 110 60 60 1Axis
259 NotHybrid
311 NewSolarNewStorage 100 100 92 92 1Axis
- NotHybrid 250 250
- NotHybrid 35 35
- NotHybrid 100 100
158.0 NotHybrid
276.0 NewSolarNewStorage 110 110 110 110 1Axis
- NotHybrid 126.59 126.59
222.0 NotHybrid
261 NotHybrid 1Axis
312 NotHybrid
23 NotHybrid
31 NotHybrid
290 NotHybrid
12 NotHybrid
37 NotHybrid
29 NotHybrid
109 NotHybrid
54 NotHybrid
136 NotHybrid
136 NotHybrid
4 NotHybrid
18 NotHybrid
84 NotHybrid
28 NotHybrid
88 NotHybrid
138 NotHybrid
190 NotHybrid
31 NotHybrid
61 NotHybrid
98 NotHybrid
3 NotHybrid Fixed
2 NotHybrid Fixed
2 NotHybrid Fixed
1 NotHybrid Fixed
2 NotHybrid Fixed
2 NotHybrid Fixed
0 NotHybrid Fixed
2 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
2 NotHybrid Fixed
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
contract_gwh_annual is_hybrid_paired can_charge_from_grid total_generator_mw contracted_generator_mw total_storage_mw contracted_storage_mw solar_technology_sub_type 0 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
3 NotHybrid Fixed
14 NotHybrid Fixed
3 NotHybrid Fixed
2 NotHybrid Fixed
14 NotHybrid Fixed
2 NotHybrid Fixed
1 NotHybrid Fixed
3 NotHybrid
500 NotHybrid Fixed
45 NotHybrid Fixed
100 NotHybrid
100 NotHybrid
50 NotHybrid
97 NotHybrid
63 NotHybrid Fixed
878 NotHybrid
- NotHybrid
1 NotHybrid
12 NotHybrid
- NotHybrid
24 NotHybrid
100 NotHybrid
8 NotHybrid
NotHybrid
NotHybrid
NotHybrid
100 NotHybrid
5 NotHybrid
21 NotHybrid
NotHybrid
NotHybrid
NotHybrid
NotHybrid
158 NotHybrid
384 NotHybrid 1Axis
NotHybrid 141.8871162 141.8871162 1Axis
NotHybrid

95.91 NotHybrid
424.91 NotHybrid
460 NotHybrid 1Axis
NotHybrid 170.2413976 170.2413976 1Axis
460 NotHybrid 1Axis
NotHybrid 170.2413976 170.2413976 1Axis
460 NotHybrid 1Axis
NotHybrid 170.2413976 170.2413976 1Axis
318.68 NotHybrid
622 NotHybrid 1Axis
NotHybrid 0 0 1Axis
622 NotHybrid 1Axis
NotHybrid 230 230 1Axis
622 NotHybrid 1Axis
NotHybrid 230 230 1Axis
502.21 NotHybrid
502.2053906 NotHybrid
463 NotHybrid 1Axis
NotHybrid 171 171 1Axis
463 NotHybrid 1Axis
463 NotHybrid 1Axis
594.82 NotHybrid
2,537
634
287
- NotHybrid 185 185
NotHybrid 25 25
878 NotHybrid
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
contract_gwh_annual is_hybrid_paired can_charge_from_grid total_generator_mw contracted_generator_mw total_storage_mw contracted_storage_mw solar_technology_sub_type lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
storage_technology_sub_type total_storage_depth_mwh contracted_storage_depth_mwh viability_cod_reasonableness viability_technical_feasibility viability_financing_sitecontrol resource_mix Li 240 240
Li 368 368
Li 1000 1000
Li 280 280
Li 400 400
Li 440 440
Li 506.36 506.36
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
storage_technology_sub_type total_storage_depth_mwh contracted_storage_depth_mwh viability_cod_reasonableness viability_technical_feasibility viability_financing_sitecontrol resource_mix Li 567.548465 567.548465
Li 1361.931181 1361.931181
Li 1361.931181 1361.931181
Li 1361.931181 1361.931181
Li 0 0
Li 1840 1840
Li 1840 1840
Li 1368 1368
Li 740 740
Li 200 200
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
storage_technology_sub_type total_storage_depth_mwh contracted_storage_depth_mwh viability_cod_reasonableness viability_technical_feasibility viability_financing_sitecontrol resource_mix lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
cam_d1911016_vamo_ghgfreepcia buy_sell_own counterparty generator_supplier developer_name capacity_area capacity_sub_area cpuc_approval_ref Clearway Energy Group SCE No_sub_area
BayWa RE PacGE No_sub_area
Clearway Energy Group SCE No_sub_area
Arevon PacGE No_sub_area
NextEra PacGE No_sub_area
NextEra PacGE No_sub_area
Humboldt House NEVP No_sub_area
LONGROAD PacGE No_sub_area
IOWN
GreaterBay
NA SCE
SPOWER SCE No_sub_area
COTTONWOOD SOLAR SCE No_sub_area
COTTONWOOD SOLAR SCE No_sub_area
RECURRENT PacGE No_sub_area
G2 Energy PacGE No_sub_area
SORENSON PacGE No_sub_area
GenPower PacGE No_sub_area
FIRST SOLAR DEVELOPMENT PacGE No_sub_area
FIRST SOLAR DEVELOPMENT PacGE No_sub_area
FIRST SOLAR DEVELOPMENT PacGE No_sub_area
FIRST SOLAR DEVELOPMENT PacGE No_sub_area
SPOWER PacGE No_sub_area
SPOWER PacGE No_sub_area
RECURRENT SCE No_sub_area
G2 Energy PacGE No_sub_area
CALPINE NorthCoastNorthBay No_sub_area
TERRA GEN SDGE No_sub_area
NEXTERA SCE No_sub_area
WM Renewable Energy PacGE No_sub_area
Calpine PacGE No_sub_area
LEEWARD PacGE No_sub_area
EDF RENEWABLES PacGE No_sub_area
SAN RAFAEL AIRPORT PacGE No_sub_area
REP ENERGY PacGE No_sub_area
BAYWA RE PacGE No_sub_area
NORTHSHORE SOLAR PARNTERS LLC PacGE No_sub_area
NORTHSHORE SOLAR PARNTERS LLC PacGE No_sub_area
DRES QUARRY, LLC PacGE No_sub_area
CALIFORNIA_SOLAR_INNOVATORS_INC_DBA_CALSOLAR GreaterBay No_sub_area RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
SAN RAFAEL AIRPORT PacGE No_sub_area
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
cam_d1911016_vamo_ghgfreepcia buy_sell_own counterparty generator_supplier developer_name capacity_area capacity_sub_area cpuc_approval_ref SMALL WORLD TRADING CO PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
RENEWABLE PROPERTIES LLC PacGE No_sub_area
NA PacGE No_sub_area
NA GreaterBay
NA PacGE
NA PacGE
NA PacGE
NA PacGE
NA SCE
NA SCE
NA PacGE
NA PacGE
AREVON Humboldt
NA SCE
NA SCE
CALPINE NorthCoastNorthBay
OHMCONNECT PacGE
WHITE PINE RENEWABLE PacGE
WHITE PINE RENEWABLE PacGE
WHITE PINE RENEWABLE PacGE

NA BANC
SHELL PacGE

CONSTELLATION BANC
PACIFIC GAS AND ELECTRIC COMPANY PacGE
PACIFIC GAS AND ELECTRIC COMPANY PacGE
PACIFIC GAS AND ELECTRIC COMPANY PacGE
SHELL PacGE
Sell CleanPowerSF NA PacGE
Sell Ava Community Energy NA PacGE
Pacific Gas & Electric
Pacific Gas & Electric
Pacific Gas & Electric
Pacific Gas & Electric
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy
Buy NA
Buy
CALPINE NorthCoastNorthBay
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
cam_d1911016_vamo_ghgfreepcia buy_sell_own counterparty generator_supplier developer_name capacity_area capacity_sub_area cpuc_approval_ref lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
county COD_year COD_month COD_day contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year contract_end_date_month SanBernardinoCounty 2023 8 25 2023 8 25 2038 8
SantaBarbaraCounty 2023 12 20 2023 12 20 2038 12
KernCounty 2025 8 8 2025 8 12 2040 8
SanMateoCounty 2027 8 1 2027 8 1 2042 7
FresnoCounty 2027 4 1 2027 4 1 2042 3
SolanoCounty 2027 4 1 2027 4 1 2042 3
Nevada 2028 2 1 2028 2 1 2049 1
SanBenitoCounty 2031 5 1 2031 5 1 2051 4
Nevada 2027 3 1 2027 3 1 2042 2
AlamedaCounty 2027 1 1 2028 10 1 2048 9
RiversideCounty 2020 12 1 2020 12 1 2040 12
LosAngelesCounty 2018 12 24 2018 12 24 2038 12
KingsCounty 2018 1 1 2018 1 1 2040 4
KernCounty 2018 1 1 2018 1 1 2040 4
FresnoCounty 2018 4 14 2018 4 14 2033 4
SolanoCounty 2018 1 1 2018 1 1 2033 6
KernCounty 2021 6 9 2021 7 5 2036 7
PlacerCounty 2018 1 1 2018 1 1 2033 1
FresnoCounty 2020 12 10 2020 12 10 2040 12
FresnoCounty 2020 12 10 2020 12 10 2040 12
FresnoCounty 2020 12 10 2020 12 10 2040 12
FresnoCounty 2020 12 10 2020 12 10 2040 12
ContraCostaCounty 2017 12 22 2017 12 22 2037 12
ContraCostaCounty 2017 12 22 2017 12 22 2037 12
KingsCounty 2018 1 1 2018 1 1 2032 12
YubaCounty 2018 1 1 2018 1 1 2031 8
LakeCounty 2017 1 1 2017 1 1 2026 12
KernCounty 2018 12 31 2018 12 29 2030 12
RiversideCounty 2025 1 1 2025 1 1 2039 12
MarinCounty 2017 9 14 2017 9 14 2037 9
SonomaCounty 2025 6 1 2025 6 1 2045 5
ContraCostaCounty 2028 1 1 2028 1 1 2035 12
MarinCounty 2018 1 1 2018 1 1 2040 4
MarinCounty 2018 1 1 2018 1 1 2032 10
MarinCounty 2018 1 1 2018 1 1 2037 2
MarinCounty 2016 9 1 2016 9 1 2036 8
MarinCounty 2016 10 6 2016 10 6 2036 10
MarinCounty 2016 10 6 2016 10 6 2036 10
MarinCounty 2019 5 14 2019 5 14 2029 12
ContraCostaCounty 2020 1 1 2020 1 1 2038 7
NapaCounty 2020 12 11 2020 12 11 2040 12
NapaCounty 2020 12 11 2020 12 11 2040 12
SolanoCounty 2019 9 1 2019 9 1 2039 8
SolanoCounty 2019 9 1 2019 9 1 2039 8
SolanoCounty 2019 9 1 2019 9 1 2039 8
MarinCounty 2020 9 30 2020 9 30 2040 9
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
county COD_year COD_month COD_day contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year contract_end_date_month MarinCounty 2018 12 10 2018 12 10 2038 12
MarinCounty 2021 3 30 2021 3 30 2041 3
MarinCounty 2021 3 30 2021 3 30 2041 3
MarinCounty 2021 3 30 2021 3 30 2041 3
SolanoCounty 2021 12 31 2021 12 31 2041 9
ContraCostaCounty 2023 6 6 2023 6 6 2043 6
ContraCostaCounty 2022 8 5 2022 8 5 2042 8
ContraCostaCounty 2022 11 30 2022 11 30 2042 11
SonomaCounty 2024 3 31 2024 1 29 2044 1
NapaCounty 2023 6 21 2023 7 13 2043 6
MarinCounty 2022 9 27 2022 9 27 2032 9
KernCounty 2027 1 1 2027 1 1 2027 5
KernCounty 2025 1 1 2025 1 1 2026 12
FresnoCounty 2026 1 1 2026 1 1 2026 12
FresnoCounty 2025 1 1 2025 1 1 2026 12
Nevada 2025 1 1 2025 1 1 2027 12
KernCounty 2015 12 1 2026 1 1 2026 12
RiversideCounty 2024 4 1 2024 4 1 2026 3
2027 6 1 2027 6 1 2037 5
California 2023 1 1 2023 1 1 2032 12
FresnoCounty 2026 1 27 2026 1 27 2046 1
FresnoCounty 2026 1 27 2026 1 27 2046 1
FresnoCounty 2026 1 27 2026 1 27 2046 1
California 2025 1 1 2025 1 1 2054 12
SiskiyouCounty 2025 1 1 2025 1 1 2027 12
Oregon 2026 1 1 2026 1 1 2027 12
PlumasCounty 2026 1 1 2026 1 1 2026 12
PlumasCounty 2026 1 1 2026 1 1 2026 12
PlumasCounty 2026 1 1 2026 1 1 2030 12
PlumasCounty 2027 1 1 2027 1 1 2027 12
KingsCounty 2022 5 15 2022 5 15 2026 12
KingsCounty 2026 1 1 2026 1 1 2026 12
2023 1 1 2045 12
2023 1 1 2045 12
2023 1 1 2045 12
2023 1 1 2045 12
2032 1 1 2052 12
2030 1 1 2050 12
2030 1 1 2050 12
2030 1 1 2050 12
2030 1 1 2050 12
2035 1 1 2055 12
2033 1 1 2053 12
2033 1 1 2053 12
2034 1 1 2054 12
2034 1 1 2054 12
2035 1 1 2055 12
2035 1 1 2055 12
2035 1 1 2055 12
2038 1 1 2058 12
2038 1 1 2058 12
2039 1 1 2059 12
2039 1 1 2059 12
2040 1 1 2060 12
2040 1 1 2060 12
2036 1 1 2056 12
2040 1 1 2060 12
2043 1 1 2058 12
2043 1 1 2058 12
2044 1 1 2059 12
2045 1 1 2060 12
2045 1 1 2060 12
2028 1 1 2045 12
2028 1 1 2045 12
2027 1 1 2045 12
2030 1 1 2030 1 1 2045 12
2032 1 1 2052 12
2037 6 1 2037 6 1 2047 5
2026 1 1 2026 12
2027 1 1 2027 12
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
county COD_year COD_month COD_day contract_start_date_year contract_start_date_month contract_start_date_day contract_end_date_year contract_end_date_month 2028 1 1 2028 12
2029 1 1 2029 12
2030 1 1 2030 12
2031 1 1 2031 12
2032 1 1 2032 12
2033 1 1 2033 12
2034 1 1 2034 12
2035 1 1 2035 12
2036 1 1 2036 12
2037 1 1 2037 12
2038 1 1 2038 12
2039 1 1 2039 12
2040 1 1 2040 12
2041 1 1 2041 12
2042 1 1 2042 12
2043 1 1 2043 12
2044 1 1 2044 12
2045 1 1 2045 12
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
contract_end_date_day contract_execution_date_year contract_execution_date_month contract_execution_date_day tx_upgrades tx_upgrade_date_year tx_upgrade_date_month tx_upgrade_date_day 24 2020 9 25
19 2018 10 19
11 2022 2 4
31 2024 1 12
31 2023 10 20
31 2023 10 20
31 2022 11 22
30 2025 2 14
28 2025 10 14
30 2025 9 5
16 2016 11 18
31 2016 11 15
30 2011 7 8
30 2011 7 8
13 2016 9 15
30 2010 12 3
4 2020 1 22
31 2012 7 6
9 2016 9 23
9 2016 9 23
9 2016 9 23
9 2016 9 23
21 2017 5 30
21 2017 5 30
31 2014 10 3
31 2010 12 3
31 2013 7 11
28 2016 12 5
31 2023 3 17
13 2014 11 6
31 2023 2 28
31 2025 10 14
30 2011 7 8
22 2012 5 8
28 2014 10 7
31 2015 4 14
5 2015 9 4
5 2015 9 4
31 2018 3 28
30 2018 5 8
10 2018 8 30
10 2018 8 30
31 2018 8 30
31 2018 8 30
31 2018 8 30
29 2018 10 24
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
contract_end_date_day contract_execution_date_year contract_execution_date_month contract_execution_date_day tx_upgrades tx_upgrade_date_year tx_upgrade_date_month tx_upgrade_date_day 9 2018 10 31
29 2019 3 7
29 2019 3 7
29 2019 3 7
29 2020 7 29
5 2020 12 11
4 2021 3 8
29 2021 3 29
28 2021 4 5
20 2021 4 14
26 2021 7 6
31 2024 7 1
31 2024 8 7
1 2024 11 26
31 2024 12 12
31 2024 12 13
31 2025 12 2
31 2023 8 18
31 2023 2 28
31 2022 8 31
26 2022 3 20
26 2022 3 20
26 2022 3 20
31 2021 3 18
31 2024 6 12
31 2025 4 18
31 2025 8 26
31 2025 12 4
31 2025 12 4
31 2025 12 10
31 2022 5 6
31 2025 12 24
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
contract_end_date_day contract_execution_date_year contract_execution_date_month contract_execution_date_day tx_upgrades tx_upgrade_date_year tx_upgrade_date_month tx_upgrade_date_day 31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
31 31
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
tx_upgrade_description d2106035_procurement_cat mtr_tranche1_NQC mtr_tranche2_NQC mtr_tranche3_NQC mtr_tranche4_NQC mtr_tranche5_NQC mtr_tranche6_NQC general 7.508 0.908
general 15.403
general
general 149.89 41.61
long_duration_storage 30.49
general 74
firm_ZE 18.56
general
general 54.27
general
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
firm_ZE 6.496
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
tx_upgrade_description d2106035_procurement_cat mtr_tranche1_NQC mtr_tranche2_NQC mtr_tranche3_NQC mtr_tranche4_NQC mtr_tranche5_NQC mtr_tranche6_NQC NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
tx_upgrade_description d2106035_procurement_cat mtr_tranche1_NQC mtr_tranche2_NQC mtr_tranche3_NQC mtr_tranche4_NQC mtr_tranche5_NQC mtr_tranche6_NQC NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
mtr_NQC_ZE_gen_paired_dr mtr_bridge_to contract_changed previous_COD_year previous_COD_month previous_COD_day remediation_plan signed_contract notice_to_proceed lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
mtr_NQC_ZE_gen_paired_dr mtr_bridge_to contract_changed previous_COD_year previous_COD_month previous_COD_day remediation_plan signed_contract notice_to_proceed lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
mtr_NQC_ZE_gen_paired_dr mtr_bridge_to contract_changed previous_COD_year previous_COD_month previous_COD_day remediation_plan signed_contract notice_to_proceed lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
public_contract buying_energy_capacity NQC_reporting_source procurement_origin planned_project_retention_priority csp_resource_category Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Hybrid_or_Paired_Solar_and_Battery (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Wind New PG&E (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS, D.21-06-035 Hybrid_or_Paired_Solar_and_Battery (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated D.23-02-040 Battery Storage (MWh Energy Capacity) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated D.2106035 Battery Storage (MWh Energy Capacity) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated D.23-02-040 Battery Storage (MWh Energy Capacity) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated D.2106035 Geothermal (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated Hybrid_or_Paired_Solar_and_Battery (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RA Battery Storage (MWh Energy Capacity) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Wind Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Biomass (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Small Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Biomass (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Biomass (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Geothermal (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Wind Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Wind Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Biogas (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated D.2106035 Geothermal (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS, RA Wind New PG&E (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
public_contract buying_energy_capacity NQC_reporting_source procurement_origin planned_project_retention_priority csp_resource_category Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS,RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS,RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Biogas (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS NA Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS NA Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Distributed (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS NA Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Geothermal (GWh) Yes, but pricing and any financial information remains confidential CapacityOnly Calculated DR RA Shed DR (MW) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential CapacityOnly Calculated RA Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Nuclear (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Large Hydro (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated Carbon Free Solar Baseline California (GWh) Yes, but pricing and any financial information remains confidential EnergyOnly Calculated RPS Solar Baseline California (GWh) CapacityOnly Allocation NA
CapacityOnly Allocation NA
CapacityOnly Allocation NA
CapacityOnly Allocation NA
EnergyCapacity RPS Geothermal (GWh)
EnergyCapacity RPS Solar New PG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Wind Baseline California (GWh)
EnergyCapacity RPS Wind New Mexico (GWh)
EnergyCapacity RPS Geothermal (GWh)
EnergyCapacity RPS Solar New PG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Solar New SCE SDG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Solar New SCE SDG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Wind Baseline California (GWh)
EnergyCapacity RPS Solar New PG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Solar New SCE SDG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Solar New SCE SDG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Wind New Mexico (GWh)
EnergyCapacity RPS Wind Wyoming (GWh)
EnergyCapacity RPS Solar New PG&E (GWh)
EnergyCapacity RA Battery Storage (MWh Energy Capacity) EnergyCapacity RPS Solar New PG&E (GWh)
EnergyCapacity RPS Solar New SCE SDG&E (GWh)
EnergyCapacity RPS Wind New Mexico (GWh)
EnergyOnly RPS Solar Baseline California (GWh)
EnergyOnly RPS Wind Baseline California (GWh)
EnergyOnly Carbon Free Large Hydro (GWh)
EnergyCapacity Calculated RA Battery Storage (MWh Energy Capacity) EnergyCapacity RA Battery Storage (MWh Energy Capacity) Yes, but pricing and any financial information remains confidential EnergyCapacity Calculated RPS Geothermal (GWh) CapacityOnly RA NA
CapacityOnly RA NA
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
public_contract buying_energy_capacity NQC_reporting_source procurement_origin planned_project_retention_priority csp_resource_category CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
CapacityOnly RA NA
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
csp_annual_2028 csp_annual_2030 csp_annual_2035 csp_annual_2040 csp_annual_2045 macro_supertype 316.91 316.27 316.27 - - physical
234.72 234.35 234.35 - - physical
317.15 313.93 305.89 213.88 - newgeneric
1,000.00 1,000.00 1,000.00 1,000.00 - newgeneric
280.00 280.00 280.00 280.00 - newgeneric
400.00 400.00 400.00 400.00 - newgeneric
157.96 157.96 157.97 158.47 158.28 newgeneric
- - 270.27 262.26 254.48 newgeneric
506.36 506.36 506.36 506.36 - newgeneric

33.45 222.86 222.86 223.26 222.86 newgeneric
197.23 196.82 196.82 191.24 - physical
247.97 247.57 247.57 - - physical

22.88 22.84 22.84 6.32 - physical

31.54 31.48 31.48 7.73 - physical
282.70 282.17 - - - physical

12.02 11.99 - - - physical

37.00 37.00 37.00 - - physical

29.49 29.44 - - - physical

82.60 82.43 82.43 80.09 - physical

26.77 26.71 26.71 25.48 - physical

45.41 45.30 45.30 42.28 - physical
127.84 127.60 127.60 124.56 - physical

3.90 3.89 3.89 - - physical

17.65 17.62 17.62 - - physical

65.40 65.31 - - - physical

28.23 28.15 - - - physical
- - - - - physical
151.47 150.56 - - - physical
189.97 189.97 189.97 - - physical

30.48 30.39 30.39 - - physical

61.00 61.00 61.00 - - existinggeneric

98.15 96.03 26.99 - - newgeneric

2.49 2.45 2.38 0.66 - existinggeneric

1.65 1.65 - - - existinggeneric

2.00 2.00 2.00 - - existinggeneric

0.50 0.50 0.50 - - existinggeneric

1.80 1.80 1.80 - - existinggeneric

0.09 - - - - existinggeneric

1.60 1.60 1.60 - - existinggeneric

2.60 2.60 2.60 2.52 - existinggeneric

2.65 2.65 2.65 - - existinggeneric

2.04 2.04 2.04 1.63 - existinggeneric
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
csp_annual_2028 csp_annual_2030 csp_annual_2035 csp_annual_2040 csp_annual_2045 macro_supertype

0.09 - - - - existinggeneric

2.56 2.51 2.46 2.41 - existinggeneric

13.43 13.29 12.95 12.60 - physical

2.66 2.63 2.57 2.50 - existinggeneric

1.62 1.62 1.62 1.62 - existinggeneric

13.65 13.51 13.16 12.81 - existinggeneric

1.90 1.90 1.90 1.90 - existinggeneric

1.05 1.05 1.05 1.05 - existing generic

3.47 3.46 - - - existinggeneric
- - - - - existinggeneric
- - - - - existinggeneric
- - - - - existinggeneric
- - - - - existinggeneric
- - - - - physical
- - - - - existinggeneric
- - - - - existinggeneric
878.40 876.00 876.00 - - existinggeneric
180.00 180.00 - - - existinggeneric

0.66 0.65 0.64 0.62 0.62 existinggeneric

12.15 12.00 11.71 11.44 11.42 physical
physical

24.51 24.50 24.50 24.51 - existinggeneric
- - - - - existinggeneric
- - - - - existinggeneric
existinggeneric
existinggeneric
existinggeneric
- - - - - existinggeneric
- - - - physical
- - - - physical
existinggeneric
existinggeneric
existinggeneric
existinggeneric
158.00 158.00 158.00 newgeneric
383.65 383.65 383.65 383.65 newgeneric
567.548465 567.548465 567.548465 567.548465 newgeneric
newgeneric

95.91 95.91 95.91 95.91 newgeneric
424.91 424.91 424.91 newgeneric
460.32 460.32 460.32 newgeneric
1361.6 1361.6 1361.6 newgeneric
460.32 460.32 460.32 newgeneric
1361.6 1361.6 1361.6 newgeneric
460.32 460.32 460.32 newgeneric
1361.6 1361.6 1361.6 newgeneric
318.68 318.68 318.68 newgeneric
- 621.78 621.78 newgeneric
- - - newgeneric
- 621.78 621.78 newgeneric
- 1840 1840 newgeneric
- 621.78 621.78 newgeneric
- 1840 1840 newgeneric
502.21 502.21 newgeneric
502.2053906 502.2053906 newgeneric
- newgeneric
1368 newgeneric
- newgeneric
462.64 newgeneric
594.82 newgeneric
472.52 626.42 547.21 612.56 341.25 existinggeneric
118.13 456.61 136.80 153.14 85.31 existinggeneric
867.76 500.00 532.01 595.55 500.00 existinggeneric
740 740 740 740 newgeneric
200 200 200 newgeneric
- - - - 876.00 existinggeneric
existinggeneric
existinggeneric
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
csp_annual_2028 csp_annual_2030 csp_annual_2035 csp_annual_2040 csp_annual_2045 macro_supertype existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
existinggeneric
lse_unique_contract_id
Daggett_Solar_Generic
Strauss_PCC1_MCE
Golden_Fields_Solar_Generic
Cormorant_Storage_MCE
Key_Storage_LD_MCE
Corby_Storage_MCE
Humboldt House_PCC1_MCE
Allium_PCC1_MCE
Roccasecca_Storage_MCE
Mulqueeney_Wind_PCC1_MCE
Desert Harvest_MCE
Antelope 2_MCE
Corcoran_MCE
Goose Lake_MCE
Great Valley_MCE
Hay_MCE
Kern Tule_PCC1_1_LT_MCE
Lincoln_MCE
Little Bear 1_MCE
Little Bear 3_MCE
Little Bear 4_MCE
Little Bear 5_MCE
MCE Solar 1_2.0_MCE
MCE Solar 1_8.5_MCE
Mustang_MCE
Ostrom_MCE
Geysers_MCE
Voyager II_MCE
Windpower_PCC1_1_LT_MCE_Update
Redwood Landfill_MCE
Geysers_PCC1_2_LT_MCE
Buena Vista_PCC1_1_MCE
Buck_MCE
SR Airport_MCE
Cooley I_MCE
Cost Plus_MCE
Freethy 1_MCE
Freethy 2_MCE
Cooley_DRES Quarry 2.4_MCE
Oakley RV & Boat Storage_MCE
Soscal Ferry Solar C_MCE
Soscal Ferry Solar D_MCE
American Canyon Solar A_MCE
American Canyon Solar B_MCE
American Canyon Solar C_MCE
SR Airport 2_MCE
notes
5be
pte
th
l
f
ep
qu
d
ibi
r ard
e
MC
lse_unique_contract_id
EO Products_MCE
Silveira Ranch A_MCE
Silveira Ranch B_MCE
Silveira Ranch C_MCE
Lake Herman_PCC1_1_LT_MCE
Byron Hot Springs_PCC1_2_LT_MCE
Oakley Phase 3_PCC1_1_LT_MCE
Byron Highway_PCC1_1_LT_MCE
Fallon_PCC1_1_LT_MCE
Napa Self Storage_PCC1_1_LT_MCE
CMSA_Updated_PCC1_2_LT_MCE
26SB 8me_PCC1_1_MCE
TEA_PCC1_4_MCE
TEA_PCC1_13_MCE
BP_PCC1_1_MCE
Townsite_PCC1_1_MCE
SDG&E_PCC1_1_MCE
ARICA_PCC1_1_MCE
GPC_PCC1_1_LT_MCE
RESI_RA_2_NS_MCE
Conflitti Jr_PCC1_DAC_1_LT_MCE
Conflitti_PCC1_DAC_2_LT_MCE
CES Electron Farm_RA_1_NS_MCE
WAPA_BR_2_MCE
SENA_CF_16_MCE
CONSTEL_ACS_1_MCE
PG&E_Hydro_7_MCE
PG&E_Hydro_8_MCE_Allocation
PG&E_Nuke_2_MCE_Allocation
SENA_CF_17_MCE
CCSF_PCC1_Sell_1_MCE
EBCE_PCC1_Sell_2_MCE
CAM - DR Allocation
CAM - Peaker Allocation
CAM - Storage
Other CAM
LT Geothermal 1
LT Solar 1
LT Storage 1
LT Wind CA 1
LT Wind Out of State 1
LT Geothermal 2
LT Solar 2a
LT Storage 2a
LT Solar 2b
LT Storage 2b
LT Solar 2c
LT Storage 2c
LT Wind CA 2
LT Solar 3a
LT Storage 3a
LT Solar 3b
LT Storage 3b
LT Solar 3c
LT Storage 3c
LT Wind Out of State 3a
LT Wind Out of State 3b
LT Solar 4a
LT Storage 4a
LT Solar 4b
LT Solar 4c
LT Wind Out of State 4
ST Solar
ST Wind
ST Large Hydro
LT Storage 0
LT LD Storage 1
GPC_PCC1_1_LT_MCE_renewal
Generic CCGT RA_2026
Generic CCGT RA_2027
notes
lse_unique_contract_id
Generic CCGT RA_2028
Generic CCGT RA_2029
Generic CCGT RA_2030
Generic CCGT RA_2031
Generic CCGT RA_2032
Generic CCGT RA_2033
Generic CCGT RA_2034
Generic CCGT RA_2035
Generic CCGT RA_2036
Generic CCGT RA_2037
Generic CCGT RA_2038
Generic CCGT RA_2039
Generic CCGT RA_2040
Generic CCGT RA_2041
Generic CCGT RA_2042
Generic CCGT RA_2043
Generic CCGT RA_2044
Generic CCGT RA_2045
notes
Reliability Need - updated with 2025 Filing Requirements release 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 CAISO gross peak (MW)
PRM (%)
CAISO Total Reliability Need (TRN) (MW)
CAISO Reliability Procurement Need (RPN) (MW)
LSE share of load during critical hours (%)
LSE reliability procurement requirement (RPR) (MW)
BTM PV Forecast - updated with 2025 Filing Requirements release 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 Capacity (MW)
ELCC (%) - updated with 2025 Filing Requirements release Resource Type 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 in_state_wind_south 20% 18% 15% 15% 15% 16% 17% 18% 19% 19% 18% 16% 14% 12% 11% 11% 11% 11% 12% 12% in_state_wind_north 30% 28% 26% 31% 35% 35% 35% 35% 35% 35% 33% 31% 28% 26% 24% 24% 24% 25% 25% 26% out_of_state_wind_WY 44% 44% 44% 41% 37% 38% 39% 40% 41% 41% 39% 37% 35% 33% 30% 32% 33% 35% 36% 38% out_of_state_wind_IDWAOR 27% 22% 17% 21% 25% 26% 27% 27% 28% 29% 27% 25% 23% 22% 20% 20% 20% 19% 19% 19% out_of_state_wind_AZNM 43% 43% 43% 39% 36% 37% 38% 40% 41% 42% 39% 37% 34% 32% 29% 30% 31% 32% 33% 34% offshore_wind_north 62% 65% 69% 63% 57% 55% 53% 51% 48% 46% 44% 42% 40% 38% 36% 36% 36% 36% 36% 36% offshore_wind_south 42% 45% 47% 39% 30% 29% 28% 26% 25% 23% 22% 20% 19% 18% 16% 17% 19% 20% 21% 22% utility_pv 8% 9% 10% 10% 10% 11% 11% 11% 11% 11% 11% 12% 12% 13% 13% 13% 12% 12% 11% 11% btm_pv 7% 8% 8% 8% 7% 8% 8% 8% 9% 9% 10% 10% 10% 11% 11% 11% 10% 10% 9% 9% 4hr_batteries 92% 84% 75% 49% 22% 21% 20% 19% 18% 17% 17% 17% 17% 17% 17% 17% 17% 16% 16% 16% 8hr_batteries 97% 92% 87% 63% 39% 36% 32% 29% 25% 22% 24% 25% 27% 28% 30% 30% 31% 31% 32% 32% 12hr_batteries 94% 92% 91% 69% 47% 42% 37% 32% 27% 22% 24% 25% 27% 28% 30% 30% 31% 31% 32% 32% 24hr_batteries 96% 94% 92% 74% 56% 50% 44% 37% 31% 25% 27% 29% 30% 32% 34% 34% 34% 34% 34% 35% 100hr_batteries 99% 99% 98% 86% 74% 69% 64% 58% 53% 48% 49% 50% 51% 52% 53% 53% 52% 52% 51% 51% pumped_storage 90% 87% 85% 66% 48% 43% 37% 32% 27% 22% 24% 25% 27% 28% 30% 30% 31% 31% 32% 32% demand_response 94% 85% 76% 59% 42% 36% 30% 24% 18% 12% 12% 11% 11% 11% 11% 10% 10% 10% 9% 9% hydro 69% 66% 63% 57% 50% 48% 46% 44% 43% 41% 40% 39% 39% 38% 37% 36% 36% 35% 35% 34% small_hydro 42% 39% 36% 33% 30% 28% 26% 24% 22% 21% 21% 21% 21% 21% 21% 20% 20% 20% 19% 19% geothermal 91% 91% 92% 89% 87% 87% 87% 87% 87% 87% 87% 88% 88% 88% 88% 89% 89% 89% 89% 90% biomass_wood 100% 99% 99% 99% 99% 99% 99% 98% 98% 98% 98% 98% 99% 99% 99% 99% 98% 98% 98% 98% biogas 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% 99% nuclear 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% 100% gas_cc 86% 85% 85% 83% 82% 82% 82% 83% 83% 83% 84% 85% 86% 87% 88% 87% 87% 86% 85% 84% gas_ct 69% 69% 69% 65% 62% 62% 62% 62% 61% 61% 64% 66% 69% 71% 74% 72% 71% 70% 68% 67% cogen 92% 91% 91% 91% 90% 90% 90% 90% 90% 90% 91% 92% 92% 93% N/A N/A N/A N/A N/A N/A ice 94% 94% 94% 94% 93% 93% 93% 93% 93% 93% 94% 94% 95% 95% 96% 95% 95% 95% 94% 94% Out of state Wind 38% 36% 35% 34% 33% 34% 35% 36% 36% 37% 35% 33% 31% 29% 27% 27% 28% 29% 30% 30% In state wind 25% 23% 21% 23% 25% 26% 26% 26% 27% 27% 25% 23% 21% 19% 17% 17% 18% 18% 18% 19% Contract ELCC (effective MW)
Resource Type Conrtact Status 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 hybrid Online
in_state_wind_south Online
in_state_wind_north Online
out_of_state_wind_WY Online
out_of_state_wind_IDWAOR Online
out_of_state_wind_AZNM Online
offshore_wind_north Online
offshore_wind_south Online
utility_pv Online
btm_pv Online
4hr_batteries Online
8hr_batteries Online
12hr_batteries Online
24hr_batteries Online
100hr_batteries Online
pumped_storage Online
demand_response Online
hydro Online
small_hydro Online
geothermal Online
biomass_wood Online
biogas Online
nuclear Online
gas_cc Online
gas_ct Online
cogen Online
ice Online
hybrid Development
in_state_wind_south Development
in_state_wind_north Development
out_of_state_wind_WY Development
out_of_state_wind_IDWAOR Development
out_of_state_wind_AZNM Development
offshore_wind_north Development
offshore_wind_south Development
utility_pv Development
btm_pv Development
4hr_batteries Development
8hr_batteries Development
12hr_batteries Development
24hr_batteries Development
100hr_batteries Development
pumped_storage Development
demand_response Development
hydro Development
small_hydro Development
geothermal Development
biomass_wood Development
biogas Development
nuclear Development
gas_cc Development
gas_ct Development
cogen Development
ice Development
hybrid Review
in_state_wind_south Review
in_state_wind_north Review
out_of_state_wind_WY Review
out_of_state_wind_IDWAOR Review
out_of_state_wind_AZNM Review
offshore_wind_north Review
offshore_wind_south Review
utility_pv Review
btm_pv Review
4hr_batteries Review
8hr_batteries Review
12hr_batteries Review
24hr_batteries Review
100hr_batteries Review
pumped_storage Review
demand_response Review
hydro Review
small_hydro Review
geothermal Review
biomass_wood Review
biogas Review
nuclear Review
gas_cc Review
gas_ct Review
cogen Review
ice Review
hybrid PlannedExisting
in_state_wind_south PlannedExisting
in_state_wind_north PlannedExisting
out_of_state_wind_WY PlannedExisting
Contract ELCC (effective MW)
Resource Type Conrtact Status 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 out_of_state_wind_IDWAOR PlannedExisting
out_of_state_wind_AZNM PlannedExisting
offshore_wind_north PlannedExisting
offshore_wind_south PlannedExisting
utility_pv PlannedExisting
btm_pv PlannedExisting
4hr_batteries PlannedExisting
8hr_batteries PlannedExisting
12hr_batteries PlannedExisting
24hr_batteries PlannedExisting
100hr_batteries PlannedExisting
pumped_storage PlannedExisting
demand_response PlannedExisting
hydro PlannedExisting
small_hydro PlannedExisting
geothermal PlannedExisting
biomass_wood PlannedExisting
biogas PlannedExisting
nuclear PlannedExisting
gas_cc PlannedExisting
gas_ct PlannedExisting
cogen PlannedExisting
ice PlannedExisting
hybrid PlannedNew
in_state_wind_south PlannedNew
in_state_wind_north PlannedNew
out_of_state_wind_WY PlannedNew
out_of_state_wind_IDWAOR PlannedNew
out_of_state_wind_AZNM PlannedNew
offshore_wind_north PlannedNew
offshore_wind_south PlannedNew
utility_pv PlannedNew
btm_pv PlannedNew
4hr_batteries PlannedNew
8hr_batteries PlannedNew
12hr_batteries PlannedNew
24hr_batteries PlannedNew
100hr_batteries PlannedNew
pumped_storage PlannedNew
demand_response PlannedNew
hydro PlannedNew
small_hydro PlannedNew
geothermal PlannedNew
biomass_wood PlannedNew
biogas PlannedNew
nuclear PlannedNew
gas_cc PlannedNew
gas_ct PlannedNew
cogen PlannedNew
ice PlannedNew
LSE total supply (effective MW)
Contract ELCC (effective MW)
Resource Type Conrtact Status 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 Load and Resource Table by Resource Type
2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 LSE reliability need (MW)
ELCC by resource type (effective MW)
hybrid
in_state_wind_south
in_state_wind_north
out_of_state_wind_WY
out_of_state_wind_IDWAOR
out_of_state_wind_AZNM
offshore_wind_north
offshore_wind_south
utility_pv
btm_pv
4hr_batteries
8hr_batteries
12hr_batteries
24hr_batteries
100hr_batteries
pumped_storage
demand_response
hydro
small_hydro
geothermal
biomass_wood
biogas
nuclear
gas_cc
gas_ct
cogen
ice
LSE total supply (effective MW)
Net capacity position (+ve = excess, -ve = shortfall) (effective MW) Load and Resource Table by Contract Status
2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041 2042 2043 2044 2045 LSE reliability need (MW)
ELCC by contract status (effective MW)
Online
Development
Review
PlannedExisting
PlannedNew
BTM PV
LSE total supply (effective MW)
Net capacity position (+ve = excess, -ve = shortfall) (effective MW) 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044
MW
LSE Capacity by Resource Type hybrid
in_state_wind_south
in_state_wind_north
out_of_state_wind_WY
out_of_state_wind_IDWAOR
out_of_state_wind_AZNM
offshore_wind_north
offshore_wind_south
utility_pv
btm_pv
4hr_batteries
8hr_batteries
12hr_batteries
24hr_batteries
100hr_batteries
pumped_storage
demand_response
hydro
small_hydro
geothermal
biomass_wood
biogas
nuclear
gas_cc
gas_ct
cogen
ice
LSE reliability need (MW)
2026 2028 2030 2032 2034 2036 2038 2040 2042 2044
MW
LSE Capacity by Contract Status
BTM PV
PlannedNew
PlannedExisting
Review
Development
Online
LSE reliability need (MW)
Resource 2028 2030 2035 2040 2045 Units Type
Large Hydro 892 524 557 620 500 GWh GHG-Free
Imported Hydro - - - - - GWh GHG-Free
Asset Controlling Supplier - - - - - GWh GHG-Free (Partial) Nuclear 570 570 - - - GWh GHG-Free
Biogas 34 34 - 30 - GWh RPS Eligible
Biomass 70 - 70 - - GWh RPS Eligible
Geothermal 1,097 1,095 1,678 741 1,617 GWh RPS Eligible Small Hydro 37 37 - 37 - GWh RPS Eligible
Wind Resources
Wind Baseline California 493 1,020 868 695 627 GWh RPS Eligible Wind New PG&E 333 330 261 - - GWh RPS Eligible
Wind New SCE SDG&E - - - - - GWh RPS Eligible
Wind Pacific Northwest - - - - - GWh RPS Eligible
Wind Wyoming - - - 502 502 GWh RPS Eligible
Wind New Mexico - 96 96 598 1,193 GWh RPS Eligible
Wind Offshore Morro Bay - - - - - GWh RPS Eligible
Wind Offshore Humboldt - - - - - GWh RPS Eligible
Solar Resources
Solar Baseline California 1,706 1,857 1,428 1,149 353 GWh RPS Eligible Solar New PG&E - 384 844 1,466 1,466 GWh RPS Eligible
Solar New SCE SDG&E - - 921 2,164 2,627 GWh RPS Eligible Solar Distributed - - - - - GWh RPS Eligible
Hybrid
Hybrid_or_Paired_Solar_and_Battery 634 630 892 476 254 GWh RPS Eligible Storage & DR
Shed DR 180 180 - - - MW GHG-Free
Pumped Storage - - - - - MW n/a
Battery Storage 2,186 3,494 7,779 11,459 10,640 MWh Energy Capacity n/a User-Specified Profies
Storage Resource Custom Profile - - - - - MW n/a
RPS Resource Custom Profile - - - - - GWh RPS Eligible
GHG-free non-RPS Resource - - - - - GWh GHG-Free
Coal
Coal - - - - - GWh n/a
Full Portfolio (Online + In-Development + Review + Planned) Resource 2028 2030 2035 2040 2045 Units RPS or GHG-Free Large Hydro 25 24 24 - 25 GWh GHG-Free
Imported Hydro - - - - - GWh GHG-Free
Asset Controlling Supplier - - - - - GWh GHG-Free (Partial) Nuclear 570 570 - - - GWh GHG-Free
Biogas 34 34 - 30 - GWh RPS
Biomass 70 - 70 - - GWh RPS
Geothermal 1,097 1,095 1,095 158 158 GWh RPS
Small Hydro 37 37 - 37 - GWh RPS
Wind Resources
Wind Baseline California 375 563 413 223 223 GWh RPS
Wind New PG&E 333 330 261 - - GWh RPS
Wind New SCE SDG&E - - - - - GWh RPS
Wind Pacific Northwest - - - - - GWh RPS
Wind Wyoming - - - - - GWh RPS
Wind New Mexico - - - - - GWh RPS
Wind Offshore Morro Bay - - - - - GWh RPS
Wind Offshore Humboldt - - - - - GWh RPS
Solar Resources
Solar Baseline California 1,234 1,231 881 537 12 GWh RPS Solar New PG&E - - - - - GWh RPS
Solar New SCE SDG&E - - - - - GWh RPS
Solar Distributed - - - - - GWh RPS
Hybrid/Paired
Hybrid or Paired Solar and Battery - - - - - GWh RPS
Storage & DR
Shed DR 180 180 - - - MW GHG-Free
Pumped Storage - - - - - MW n/a
Battery Storage 2,186 2,186 2,186 - 2,186 MWh Energy Capacity n/a User-Specified Profiles
Storage Resource Custom Profile - - - - - MW n/a
RPS Resource Custom Profile - - - - - GWh RPS
GHG-free non-RPS Resource Custom Profile - - - - - GWh GHG-Free Coal
Coal - - - - - GWh n/a
Online + In-Development Only
Attachment D
MCE 2026 IRP Clean System
Power Template
MCE's 2026 IRP Clean System Power Tool Template can be viewed at the following link:

MCE 2026 IRP Clean System Power Template
Attachment E:

Ke y Acronyms
Acronym Te rm
CAISO California Independent System Operator
CCA Community Choice Aggregator
CEC California Energy Commission
CPUC California Public Utilities Commission
CSP Clean System Power Tool
EGS Enhanced Geothermal Systems
ELCC Effective Load Carrying Capacity
ERMP Energy Risk Management Policy
GHG Greenhouse Gas
IRP Integrated Resource Plan
LSE Load Serving Entity
MTR Mid Term Reliability
PCP Preferred Conforming Portfolio
PRM Planning Reserve Margin
PSP Preferred System Plan
RA Resource Adequacy
RDT Resource Data Template
RPS Renewables Portfolio Standard
SOD Slice of Day
TPP Transmission Planning Process
July 16, 2026
TO: MCE Board of Directors
FROM: Shanelle Scales-Preston, MCE Board Chair
Cindy Darling, MCE Board Vice-Chair
Barbara Coler, MCE Executive Committee Chair
RE: Proposed Creation of Ad Hoc Civil Grand Jury Response Committee (Agenda Item #09)
Dear Members of the Board of Directors:

Summary:

On June 16, 2026, the Marin Civil Grand Jury released a report about MCE titled “MCE, Marin Clean Energy: A Series of Missteps Highlight Need for Governance Changes.” The report contains 14 factual findings and 13 recommendations, 11 of which are directed to MCE’s Board. (Two of the findings and recommendations are directed to MCE’s constituent communities in Marin required to respond with invitations to other MCE jurisdictions to respond). Pursuant to Penal Code sections 933 and 933.05, MCE’s Board of Directors has 90 days to respond. Its response is therefore due on September 14, 2026. This due date falls before the Board’s regularly scheduled September meeting, on September 17, 2026
As the Board meets only once a month and has a relatively short window for responding to the findings and recommendations, it would be a logistical challenge for the Board to complete this important responsibility in a thorough and timely fashion without delegating the laboring oar of the work to a committee. We therefore recommend creation of an Ad Hoc Grand Jury Response Committee to lead and oversee the preparation of the Board’s draft response and to submit that draft response to the full Board for review and approval. We would encourage the Ad Hoc Grand Jury Response Committee to target the Board’s August Board meeting but in the event the draft response cannot be prepared by that time, it may be necessary a convene a special meeting of the Board in September, in order to meet the September 14, 2026 due date.

Given the timing constraints and nature of the work, the Committee needs the flexibility to meet frequently, virtually, and over email, as ad hoc committees are permitted to do under the Brown Act.

To ensure appropriate transparency, however, the full Board would conduct its deliberations over the draft response at a public, noticed meeting. And, as recommended by the Executive Committee at its July 6 meeting, members of the public will be invited to provide their comments on the Grand Jury Report at this Board meeting.

We invite the Ad Hoc Grand Jury Response Committee to leverage staff and external Legal Counsel to support the committee in preparing the draft response, but defer to the Committee to identify and select the staffing resources it deems appropriate.

Given that the Committee would be responding to the Marin Civil Grand Jury, it may be appropriate for a majority of the members to be from Marin communities (however, it was noted during Executive Committee that the response is from the full Board, and it not be limited to Marin members). At the Executive Committee meeting on July 6, as two Directors initially proposed for this Committee (Sackett and McCormick) instead were recommended for the CEO Search Ad Hoc Committee, Director Perrey graciously stepped up to join this GJ Response Ad Hoc Committee. Also, at the Executive Committee meeting, it was recommended that Directors Bailey (Hercules) or Belotz (Danville) would be a great fit to “round out” the GJ Response Ad Hoc Committee to make this a committee of 5, pending their availability and willingness to serve. The following directors have kindly expressed interest and willingness to serve on this Ad Hoc Committee: Directors Andre (Larkspur), Perrey (Mill Valley), Szakats (Pleasant Hill), Walker (San Anselmo), and Belotz (Danville). It is highly recommended that the Committee is limited to no more than five members. However, at Executive Committee, the Committee requested that MCE staff send a request out to all Directors to determine if others wish to join. During this meeting, Director Belotz or others could join. The desire is to have 5 members in this Ad Hoc, not too large or too small, thus able to meet often without too many multiple scheduling conflicts.

Fiscal Impacts:

Limited costs for external Legal Counsel. Sufficient funds are available in MCE’s Fiscal Year Ending 2027 Operating Budget.

Recommendation:

Approve the Executive Committee’s unanimous recommendation of the creation of an Ad Hoc Grand Jury Response Committee, consisting of Directors Andre, Perrey, Szakats, and Walker, to lead and oversee preparation of a draft response to the June 16, 2026 Civil Grand Jury report. Other members (TBD at this Board meeting) may include Belotz (or others). The timeframe for the response is for the Board to review and approve in advance of the September 14, 2026 due date.

July 6, 2026
TO: MCE Executive Committee
FROM: Catalina Murphy, General Counsel
RE: Proposed General Counsel Reporting Structure (Agenda Item #10) ATTACHMENTS: A. Draft Resolution 2026-06 Delegating Authority Setting Compensation, Tenure, Appointment and Conditions of
Employment to the Executive Committee and the CEO
B. Resolution 2018-09 Delegating Authority Setting Compensation, Tenure, Appointment and Conditions of Employment to the Executive Committee and the CEO
C. Redline of Resolution 2018-09 Delegating Authority Setting Compensation, Tenure, Appointment and Conditions of
Employment to the Executive Committee and the CEO
Dear Executive Committee Members:

Summary:

Historically, the General Counsel position, held by an in-house employee at MCE, has reported to the Chief Executive Officer. While there may not have been direct supervisory structure by the Board, there has always been a dotted line reporting structure in place with the Board of Directors pursuant to the California Rules of Professional Conduct. Under these rules, the General Counsel represents the “organization itself, acting through its duly authorized directors, officers, employees, members, shareholders, or other constituents overseeing the particular engagement.” CRPC 1.13(a).

Both members of the Board and the legal team have desired a more clearly defined reporting structure to the Board of Directors to better align with CRPC 1.13(a). The proposed resolution provides that structure as an interim solution until the governance assessment process is completed and the reporting structure can be refined and finalized in additional governing documents.

Background
MCE has had three General Counsel employees. During MCE’s inception, the agency leveraged outside counsel as special counsel to support the agency’s legal needs. All General Counsels have reported to the CEO. The most current employee in the position is Catalina Murphy, who reports to the CEO/Acting CEO.

Until August 2023, Article VI of the Operating Rules and Regulations (“OR&R”) provided that a majority of the full Board is required to approve the hiring of the CEO and the General Counsel. In 2018, the Board of Directors adopted Resolution 2018-09. In that resolution, the Board expressly stated that it was not divesting itself of its authority over the compensation, tenure, appointment and conditions of employment of MCE employees and was retaining its authority to directly exercise such powers as “necessary and proper.” However, the resolution delegated authority to the Executive Committee to provide for the “compensation, tenure, appointment and conditions of employment of the CEO” and also delegated authority to the CEO to provide for the “compensation, tenure, appointment and conditions of employment of MCE employees.” MCE has historically interpreted Resolution 2018-09 to delegate to the CEO the Board’s authority to hire the General Counsel (authority over “compensation, tenure, appointment, and conditions of employment”), as the General Counsel is an MCE employee other than the CEO. Resolution 2018-09 was adopted by 17 communities, which was a majority of the full Board at the time. Both Ms. Murphy and her predecessor were hired by the CEO.

In 2023, the Operating Rules and Regulations (“OR&R”) were amended by your Board of Directors, removing the General Counsel position from Article VI.

Although neither the current General Counsel nor any lawyers on the MCE staff were hired directly by the Board, that fact does not alter the professional obligations of MCE in-house counsel. The client of the MCE General Counsel, and all MCE lawyers, is MCE. The rules of professional responsibility recognize that the organization acts “through its duly authorized directors, officers, employees, members, shareholders, or other constituents overseeing the particular engagement.” CRPC 1.13(a). For many operational purposes, MCE acts through its CEO, and it is logical and appropriate for the General Counsel to take direction from the CEO, as the relevant constituent on such matters. But the General Counsel’s duty of loyalty, and that of all MCE lawyers, lies with the organization, and not any individual officer or employee. While the prior hiring of the General Counsel of the CEO does not alter the General Counsel’s professional obligations, it is logical and appropriate that the Board, as MCE’s highest governing authority, have ultimate supervisory authority over the General Counsel.

While retaining the basic structure of Resolution 2018-09, the proposed resolution would rescind and replace Resolution 2018-09 and:
• make the delegation to the CEO hiring authority for all employees, except the CEO and General Counsel;
• retain without alteration the existing language of Resolution 2018-09 stating that the MCE Board retains authority over the tenure and appointment of MCE employees (this would include the General Counsel) as “necessary and proper”; • retain the delegation to the Executive Committee of authority over compensation, tenure, and conditions of employment of the CEO, but also add the General Counsel to that delegation with an obligation for the Executive Committee to timely report to the Board on such matters;
• clarify that the hiring of the CEO and General Counsel stays with the MCE Board; and • add a paragraph specifying that the General Counsel reports directly to the MCE Board.

While the power to hire is related to but distinct from reporting structure, the proposed resolution would put the General Counsel in the same existing supervisory structure as the CEO (i.e., oversight by the Executive Committee) and also explicitly state that the General Counsel reports to the Board.

This is a proposed interim approach to clearly establish a reporting line to the Board of Directors.

After the completion of the governance assessment, the Board may ultimately wish to amend the OR&R to reinstate the requirement that the hiring of the General Counsel requires a majority of the full Board. (It is implicit in Resolution 2018-09 and the proposed resolution that the Board has authority to hire the General Counsel; a potential OR&R amendment would make that explicit and specify the vote requirement for such an action.) Amendments to the OR&R, however, take multiple meetings to be effective. As there are likely to be additional recommended changes to the OR&R as a result of the governance assessment MCE is currently undergoing, staff recommend including any change regarding the General Counsel position with other potential changes to the OR&R.

The proposed resolution, which makes surgical edits to Resolution 2018-09, would be an interim solution to facilitate immediate clarification of the General Counsel’s reporting relationship pending the governance assessment. In the future, the Board may determine whether it is appropriate to revisit this interim solution.

At the July 6 Executive Committee meeting, the Committee unanimously approved the proposed resolution with requested edits to clarify that the hiring authority of the CEO and General Counsel remains with the Board of Directors. The proposed Resolution 2026-06 contains such edits.

Fiscal Impacts:

None.

Recommendation:

Approve proposed Resolution 2026-06 Delegating Authority Setting Compensation, Tenure, Appointment and Conditions of Employment to the Executive Committee and the CEO.

RESOLUTION 2026-06

A RESOLUTION OF THE BOARD OF DIRECTORS OF

MARIN CLEAN ENERGY DELEGATING AUTHORITY OF SETTING

COMPENSATION, TENURE, APPOINTMENT AND CONDITIONS OF EMPLOYMENT

TO THE EXECUTIVE COMMITTEE AND THE CHIEF EXECUTIVE OFFICER WHEREAS, Marin Clean Energy (MCE) is a joint powers authority established on December 19, 2008, and organized under the Joint Exercise of Powers Act (Government Code Section 6500 et seq.); and
WHEREAS, MCE members include the following communities: the County of Marin, the County of Contra Costa, the County of Napa, the County of Solano, the City of American Canyon, the City of Belvedere, the City of Benicia, the City of Calistoga, the City of Concord, the Town of Corte Madera, the Town of Danville, the City of El Cerrito, the Town of Fairfax, the City of Fairfield, the City of Hercules, the City of Lafayette, the City of Larkspur, the City of Martinez, the City of Mill Valley, the Town of Moraga, the City of Napa, the City of Novato, the City of Oakley, the City of Pinole, the City of Pittsburg, the City of Pleasant Hill, the City of San Ramon, the City of Richmond, the Town of Ross, the Town of San Anselmo, the City of San Pablo, the City of San Rafael, the City of Sausalito, the City of St. Helena, the Town of Tiburon, the City of Vallejo, the City of Walnut Creek, and the Town of Yountville; and
WHEREAS, consistent with Government Code Section 25300, the Board has the authority to prescribe the compensation of all MCE officers and provide for the number, compensation, tenure, appointment and conditions of employment of MCE employees; WHEREAS, in Resolution 2018-09, the Board of Directors delegated to the CEO or his or her designee authority, among other things, to provide for the number, compensation, tenure, appointment and conditions of employment MCE employees; WHEREAS, in Resolution 2018-09, the Board of Directors also delegated to the Executive Committee the authority to provide for the number, compensation, tenure, appointment and conditions of employment of the CEO;
WHEREAS, the Board of Directors seeks to improve and streamline employment matters of MCE through its delegation of authority.

WHEREAS, the Board of Directors also wishes to clarify the relationship of the General Counsel to the Board;
WHEREAS, the Board of Directors intends that this Resolution No. 2026-06 rescind and replace Resolution 2018-09;
WHEREAS, the Board of Directors, by this delegation of authority to prescribe the compensation of all MCE officers and provide for the number, compensation, tenure, appointment and conditions of employment of MCE employees as described herein, shall not be divested of any such authority, but shall retain and may exercise such authority at such times as it may deem necessary and proper, at its sole discretion; and NOW, THEREFORE, BE IT RESOLVED, that the Board of Directors of MCE does hereby resolve, determine, and order as follows:

Section 1. Resolution 2018-09 is hereby rescinded.

Section 2. The Board hereby delegates to MCE’s Chief Executive Officer (CEO) or her or his designee, in consultation with the Executive Committee, the authority to prescribe the compensation of all MCE officers, other than the CEO and the General Counsel, and provide for the number, compensation, tenure, appointment and conditions of employment of MCE employees other than the CEO and the General Counsel, provided that such prescription and provision be consistent with the Board-approved budget.

Section 3. The Board hereby delegates to the Executive Committee the authority to prescribe the compensation of MCE’s CEO and General Counsel and provide for the compensation, tenure, and conditions of employment of the CEO and General Counsel, provided that such prescription and provision be consistent with the Board-approved budget, and that the Executive Committee timely report out such prescriptions to the MCE Board. For the avoidance of doubt, the MCE Board retains the authority to hire the CEO and General Counsel, subject to MCE’s Operating Rules and Regulations.

Section 4. Because the General Counsel’s client is MCE, the General Counsel shall report directly to the MCE Board, as MCE’s highest governing authority, provided that this resolution does not alter the General Counsel’s obligations under the California Rules of Professional Conduct.

PASSED AND ADOPTED at a regular meeting of the MCE Board of Directors on this 16th day of July, 2026, by the following vote:

AYES NOES ABSTAIN ABSENT
County of Marin
County of Contra Costa
County of Napa
County of Solano
City of American Canyon
City of Belvedere
City of Benicia
City of Calistoga
City of Concord
Town of Corte Madera
Town of Danville
City of El Cerrito
Town of Fairfax
City of Fairfield
City of Hercules
City of Lafayette
City of Larkspur
City of Martinez
City of Mill Valley
Town of Moraga
City of Napa
City of Novato
City of Oakley
City of Pinole
City of Pittsburg
City of Pleasant Hill
City of San Ramon
City of Richmond
Town of Ross
Town of San Anselmo
City of San Pablo
City of San Rafael
City of Sausalito
City of St. Helena
Town of Tiburon
City of Vallejo
City of Walnut Creek
Town of Yountville
______________________________________

CHAIR, MCE
Attest:
___________________________________________

SECRETARY, MCE

1 RESOLUTION NO. 2018-092026-06

A RESOLUTION OF THE BOARD OF DIRECTORS OF

MARIN CLEAN ENERGY DELEGATING AUTHORITY OF SETTING

COMPENSATION, TENURE, APPOINTMENT AND CONDITIONS OF EMPLOYMENT

TO THE EXECUTIVE COMMITTEE AND THE CHIEF EXECUTIVE OFFICER WHEREAS, Marin Clean Energy (MCE) is a joint powers authority established on December 19, 2008, and organized under the Joint Exercise of Powers Act (Government Code Section 6500 et seq.); and
WHEREAS, MCE members include the following communities: MCE members include the following communities: the County of Marin, the County of Contra Costa, the County of Napa, the County of Solano, the City of American Canyon, the City of Belvedere, the City of Benicia, the City of Calistoga, the City of Concord, the Town of Corte Madera, the Town of Danville, the City of El Cerrito, the Town of Fairfax, the City of Fairfield, the City of Hercules, the City of Lafayette, the City of Larkspur, the City of Martinez, the City of Mill Valley, the Town of Moraga, the City of Napa, the City of Novato, the City of Oakley, the City of Pinole, the City of Pittsburg, the City of Pleasant Hill, the City of San Ramon, the City of Richmond, the Town of Ross, the Town of San Anselmo, the City of San Pablo, the City of San Rafael, the City of Sausalito, the City of St. Helena, the Town of Tiburon, the City of Vallejo, the City of Walnut Creek, and the Town of Yountville; and
WHEREAS, consistent with Government Code Section 2350025300, the Board has the authority to prescribe the compensation of all MCE officers and provide for the number, compensation, tenure, appointment and conditions of employment of MCE employees; and
WHEREAS, in Resolution 2018-09, the Board of Directors delegated to the CEO or his or her designee authority, among other things, to provide for the number, compensation, tenure, appointment and conditions of employment MCE employees; WHEREAS, in Resolution 2018-09, the Board of Directors also delegated to the Executive Committee the authority to provide for the number, compensation, tenure, appointment and conditions of employment of the CEO;
WHEREAS, the Board of Directors seeks to improve and streamline employment matters of MCE through its delegation of authority.

WHEREAS, the Board of Directors also wishes to clarify the relationship of the General Counsel to the Board;
WHEREAS, the Board of Directors intends that this Resolution No. 2026-06 rescind and replace Resolution 2018-09;
2 WHEREAS, the Board of Directors, by this delegation of authority to prescribe the compensation of all MCE officers and provide for the number, compensation, tenure, appointment and conditions of employment of MCE employees as described herein, shall not be divested of any such authority, but shall retain and may exercise such authority at such times as it may deem necessary and proper, at its sole discretion; and WHEREAS, the Board of Directors seeks to improve and streamline employment matters of MCE through its delegation of authority.

NOW, THEREFORE, BE IT RESOLVED, that the Board of Directors of MCE does hereby resolve, determine, and order as follows:

Section 1. Resolution 2018-09 is hereby rescinded.

Section 23. The Board hereby delegates to the Executive Committee the authority to prescribe the compensation of MCE’s CEO and General Counsel and provide for the compensation, tenure, appointment and conditions of employment of the CEO and General Counsel, provided that such prescription and provision be consistent with the Board-approved budget.

PASSED AND ADOPTED at a regular meeting of the MCE Board of Directors on this 18th16th day of October, 2018July, 2026, by the following vote:

AYES NOES ABSTAIN ABSENT
County of Marin
County of Contra Costa
County of Napa
County of Solano
City of American Canyon
City of Belvedere
City of Benicia
City of Calistoga
3 City of Concord
Town of Corte Madera
Town of Danville
City of El Cerrito
Town of Fairfax
City of Fairfield
City of Hercules
City of Lafayette
City of Larkspur
City of Martinez
City of Mill Valley
Town of Moraga
City of Napa
City of Novato
City of Oakley
City of Pinole
City of Pittsburg
City of Pleasant Hill
City of San Ramon
City of Richmond
Town of Ross
Town of San Anselmo
City of San Pablo
City of San Rafael
City of Sausalito
City of St. Helena
Town of Tiburon
City of Vallejo
City of Walnut Creek
Town of Yountville
______________________________________

CHAIR, MCE
4 Attest:
___________________________________________

SECRETARY, MCE
July 16, 2026
TO: MCE Board of Directors
FROM: Andy Twilling, Power Procurement Manager
RE: Approved Contracts for Energy Update (Agenda Item I.1) Dear MCE Board Members:

Summary:

This report summarizes contracts for energy procurements entered into by the Chief Executive Officer or their delegate and, if applicable, the Chair of the Technical Committee, since the last report was prepared for the regular Board meeting in June 2026. This summary is provided to your Board for information purposes only and no action is needed.

Review of Procurement Authorities:

In November 2020, your Board adopted Resolution 2020-04 which included the following provisions:

The CEO and Technical Committee Chair, jointly, are hereby authorized, after consultation with the appropriate Committee of the Board of Directors, to approve and execute contracts for Energy Procurement for terms of less than or equal to five years. The CEO shall timely report to the Board of Directors all such executed contracts.

The CEO is authorized to approve and execute contracts for Energy Procurement for terms of less than or equal to 12 months, which the CEO shall timely report to the Board of Directors.

The CEO is required to report all such contracts and agreements to the MCE Board of Directors on a timely basis.

Item
#
Month of
Execution Purpose Average Annual Contract Amount
Contract
Term
Date of consultation
with IAC (if applicable)
1 June, 2026 Purchase of Renewable
Energy $730,500 1 Year or less N/A
2 June, 2026 Purchase of Renewable
Energy $350,000 1 Year or less N/A
3 June, 2026 Purchase of CAISO
Energy (Hedge) $5,513,032 1 Year or less 5/20/2026
4 June, 2026 Purchase of Resource
Adequacy $99,000 1 Year or less N/A
5 June, 2026 Sale of Renewable
Energy $1,270,598 1-5 Years 5/20/2026
Contract Approval Process:

Contract Approval Process: Energy procurement is governed by MCE’s Energy Risk Management Policy as well as Board Resolutions 2020-04 and 2026-01. The Energy Risk Management Policy (Policy) has been developed to help ensure that MCE achieves its mission and adheres to its procurement policies established by the MCE Board of Directors (Board), power supply and related contract commitments, good utility practice, and all applicable laws and regulations.

The evaluation of every new energy contract is based upon how to best fill MCE’s open position.

Factors such as volume, notional value, type of product, price, term, collateral threshold and posting, and payment are all considered before execution of the agreement.

After evaluation and as part of the overall approval process, an approval matrix is implemented whereby the draft contract is routed to key MCE departments and consultants for review, input, and approval. Typically, contracts are routed for commercial, technical, legal, and financial approval, and are then typically routed through the Chief Operating Officer for approval prior to execution. The table below lists the MCE departments and consultants (and examples of relevant staff) assigned to review and approve, before the contract is forwarded to the next stage of review.

Review Owner Review Category
CB Hall (MCE, Director of Power Resources) Procurement/Commercial John Dalessi (Pacific Energy Advisors) Technical Review Steve Hall (Hall Energy Law) Legal
Nathaniel Malcolm (MCE, Senior Commercial Counsel) Legal (Process & CPUC Compliance)
Maira Strauss (MCE, Chief Financial Officer) Credit/Financial Vicken Kasarjian (COO/Acting CEO) Executive
Pursuant to Resolution 2020-04, contracts for terms of less than or equal to 12 months can be approved and executed by the CEO.

Pursuant to Resolution 2020-04 and Resolution 2026-01, MCE consults with the Interim Advisory Committee (IAC) regarding potential contracts for terms of 1-5 years. After consultation with the Interim Advisory Committee, the CEO and Technical Committee Chair are jointly authorized to approve and execute the agreement.

Fiscal Impacts:

Expenses and revenue associated with these Contracts and Agreements that are expected to occur during FYE 2027 are within the FYE 2027 Operating Fund Budget. Expenses and revenue associated with future years will be incorporated into budget planning as appropriate.

Recommendation:

Information only. No action required.

July 16, 2026
TO: MCE Board of Directors
FROM: Sabrinna Soldavini, Vice President of Policy
RE: Legislative and Regulatory Updates (Agenda Item I.2) Dear Board Members:

Summary:

Below is a summary of the key activities at the state and federal legislatures and the California Public Utilities Commission (CPUC), California Energy Commission (CEC), and the California Independent System Operator (CAISO) impacting Community Choice Aggregation (CCA) and MCE.

I. California Legislature
a. California Community Choice Association (CalCCA) Sponsored Bills Both of CalCCA’s sponsored bills (SB 1138 and AB 1761) were unanimously voted out of their second house policy committees last month and will be heard in their second house Appropriations committees in mid-August when the Legislature returns from its summer recess. MCE staff notes that this is a great time for MCE’s communities to register a support position on these bills if their city or county has not yet done so. Template letters of support were provided to the Board and can also be provided by reaching out to MCE Staff.

SB 1138 (Padilla) - Lowering Resource Adequacy Costs
SB 1138 addresses the misalignment between the CPUC’s rules for resource adequacy (RA) accounting and RA compliance. Today, RA compliance is measured on an hourly basis, meaning that load serving entities (LSEs) need to have sufficient capacity under contract to cover anticipated load during all hours of the day, all days of the year. However, RA purchases can only be made in monthly increments. This means that if an LSE needs additional capacity in just one or two hours out of a month, it must enter into a contract for the full month, rather than for only the hours it needs.

As a result, LSEs are paying for more capacity than we need, and during hours when we don’t need it. SB 1138 aligns these rules by allowing hourly load obligation trading, which is projected to save California customers more than $100 million every year based on current pricing trends.

AB 1761 (Rogers) - PCIA Data Transparency
AB 1761 would improve access and transparency for data used to calculate the Power Charge Indifference Adjustment (PCIA) and other values derived from the PCIA calculation. This transparency will enable two primary benefits. First, it will allow more parties, including CCA representatives and consumer advocates, to review complex data sets and calculation methodologies, which will increase the chance of catching any mistakes that could harm customers. The bill incorporates the robust practices already in place at the PUC that protect market-sensitive information. Second, it will allow CCAs to better forecast our customers’ PCIA rates earlier and more accurately, which will allow more time for a CCA to consider whether and how it can reduce the PCIA burden on our customers. b. Positions Taken to Date
The following table includes all the positions MCE has registered to date, including one new position discussed briefly below.

Bill Number and
Author
Subject MCE
Position
Status
AB 1761 (Rogers) PCIA data transparency Support Active
SB 1138 (Padilla) RA hourly transactability Support Active AB 2111 (Papan) Transmission planning Support Active
AB 1684 (Ward) Cooling systems in common
interest developments
Support Active
AB 2508 (Hoover) Funding for Public Purpose
Programs including energy
efficiency
Oppose Held in
Assembly
AB 2383 (Zbur) Electricity service for large data
centers
Oppose
Unless
Amended
Active
SB 1282 (Becker) Vehicle grid integration Support Held in Senate
AB 2313 (Berman) Alternatives to gas distribution
service line replacements
Support Active
AB 2369 (Rogers) Resource adequacy and full
capacity deliverability status
Support Active
SB 1265 (Richardson) GoGreen Financing Program Support Held in Assembly
AB 1577 (Bauer-Kahan)Data centers: reporting on energy
usage
Support Active
AB 1577 (Bauer-Kahan) requires the CEC to develop a process for data centers to report on several aspects of their power and water usage. The CEC would anonymously aggregate this data and publish the results on an annual basis. Data centers applying for specified permits and authorizations would be required to include this information in their applications. Beginning in 2029, the bill would require the CEC’s Integrated Energy Policy Report to include an assessment of electric load trends for data centers, and recommendations for mitigating the impact of data center load growth on the grid and on greenhouse gas emissions.

II. California Public Utilities Commission (CPUC)
a. Resource Adequacy (RA) Proceeding
On June 1, the CPUC issued a Proposed Decision (PD) in Track 1 of the RA proceeding. Most notably, the PD suggested rule changes to account for the new California Independent System Operator (CAISO) RA products of Reliability Capacity (RC) and Imbalance Reserves (IR). The proposed changes would have applied to load serving entities future and existing contracts, potentially rendering MCE’s existing RA contracts noncompliant and requiring MCE to open each of its contracts for renegotiations. This would likely result in higher RA costs as sellers would have greater negotiating power to seek additional terms.

MCE worked closely with CalCCA to submit Opening Comments requesting that the CPUC not adopt this decision or, at the least, clarify that the rule changes would not apply to existing contracts.

Several other parties shared similar concerns in Opening Comments, and CalCCA’s Reply comments emphasized this position. On June 30, the CPUC issued a Revised PD, proposing to exempt existing RA contracts from the RC/IR rules.

Other notable items in the Revised PD include:
• Rejecting Hourly Load Obligation Trading (LOT), which MCE has strongly advocated for and continues to support through the legislation of California Senate Bill 1138; and • Requiring Investor-Owned Utilities to disclose information to a CCA on data center customers expected to interconnect within the CCA’s service area in the following year.

A final Decision on Track 1 Issues is expected in early July. MCE will provide an update in its next Staff report.

In Track 2 of the RA proceeding, the CPUC is currently conducting its 2026 Loss of Load Expectation (LOLE) studies. The LOLE study models statewide grid reliability, and the final LOLE results will affect the 2028 Planning Reserve Margin (PRM), ultimately affecting MCE’s RA procurement obligations.

MCE worked with CalCCA to submit a proposal for alternative Inputs and Assumptions to the LOLE study, advocating that the studies focus on achieving a reliable grid through the most cost-effective methods.

The CPUC plans to issue its Draft 2028 LOLE studies and PRM proposals by August 14, 2026. MCE plans to work with CalCCA to file comments following the release of the studies and proposals.

Fiscal Impacts: There is no direct fiscal impact on MCE at this time. However, changes to RA policy ultimately affect MCE’s procurement costs. Specifically, changes in RA contract requirements and updates to the PRM could increase the cost of future MCE procurement. b. Power Charge Indifference Adjustment (PCIA)
In February 2025, the CPUC issued an Order Instituting Rulemaking (OIR) to update Energy Resource Recovery Account (ERRA) and Power Charge Indifference Adjustment (PCIA) policies and processes.

Per law, the CPUC is required to ensure “indifference” and prevent cost shifts between bundled and unbundled customers. This entails the Investor-Owned Utilities (IOUs), such as Pacific Gas & Electric (PG&E) recovering electricity costs from CCA customers that were incurred on their behalf before they departed PG&E service and reducing those costs by the value of benefits that remain with PG&E customers. To facilitate this process, the Commission established the PCIA, a charge paid by all customers on the PG&E side of the bill.

In this proceeding, the CPUC is evaluating potential changes to the methodology of calculating the PCIA through three tracks. Tracks 1 and 3 remain active but had no major filings and updates in June 2026.

In January 2026, the Commission issued a Scoping Memo for Track 2 of this proceeding to consider how to appropriately value pre-2019 banked Renewable Energy Certificates (RECs). All three large IOUs purchase resources and their associated RECs and “bank” a portion of them to use for compliance with the Renewable Portfolio Standard (RPS) program at a later time. The current methodology values these RECs at $0. Throughout the proceeding, MCE has worked with CalCCA to argue that this methodology shifts costs onto unbundled customers who should receive value for the resources and RECs they paid for.

In June 2026, CalCCA filed Opening and Reply Briefs continuing to advocate for the proposal that most accurately values banked RECs and ensures customer indifference. Customers that departed IOU service after the IOUs purchased and banked RECs prior to 2019 do not receive any value when IOUs use those RECs for current bundled customer compliance. CalCCA reiterated that this violates the indifference principle that unbundled customers need to receive value for resources or attributes that they paid for to avoid cost shifting. CalCCA proposed that the IOUs be required to value any pre-2019 banked RECs at the current RPS MPB and credit to the appropriate PCIA vintage. As an alternative, CalCCA proposed that the IOUs be required to allocate the RECs to the appropriate LSE and that LSEs' RPS compliance obligation should be reduced accordingly. If the RPS MPB is not adopted, CalCCA recommended that the CPUC adopt a weighted compliance value that is at 90 percent of the value of Portfolio Content Category (PCC) 1 RECs and 10 percent of the value of PCC-3 RECs.

MCE will continue to actively engage in this proceeding through 2026 and provide updates as they become available.

Fiscal Impacts: There are no immediate fiscal impacts to MCE. The PCIA is a charge on the PG&E side of the bill, but changes to the PCIA impact MCE customers’ overall bills and MCE’s rate competitiveness.
c. Energy Efficiency (EE)
In May 2026, MCE submitted reply comments to responses and protests regarding its 2028-2031 EE Portfolio Plan and 2032-2035 EE Business Plan (MCE EE Application), submitted on March 16, 2026.

MCE was one of 13 program administrators (PAs) to submit an EE application to the Commission in March 2026. In April 2026, the Administrative Law Judge consolidated all EE applications into one proceeding and allowed protests and responses in May 2026. Several parties, including some PAs, submitted responses to the EE applications addressing policy recommendations, the preferred scope of the proceeding, the proposed schedule, and the Commission’s oversight of EE portfolios.

Four parties submitted protests on some, or all, of the EE Applications. The Public Advocates Office protested all EE Applications requesting a focus on energy affordability in the review of all submissions. Additionally, a group of labor organizations protested all EE Applications requesting inclusion of workforce standards and support for high road jobs in EE portfolios.

In its reply, MCE supported advancing energy affordability through EE programs and provided citations within its application demonstrating that commitment. Similarly, MCE expressed support for workforce standards and high-road jobs and cited portions of its March application describing that support. MCE anticipates having more information about the proposed scope and schedule of the EE application proceeding following the June 2026 prehearing conference.

Fiscal Impacts: If approved, MCE will be authorized to receive and administer $133,096,000 dollars for EE programs from 2028-2035.

July 16, 2026
TO: MCE Board of Directors
FROM: Alice Havenar-Daughton, VP of Customer Programs
Jamie Tuckey, Chief Customer Officer
RE: Customer Programs Update (Agenda Item I.3)
ATTACHMENT: Customer Programs Metrics
Dear MCE Board Members:

Summary:

The following tables provide key metrics on current MCE Customer Programs. CPUC-funded energy efficiency programs operate on a calendar year basis, whereas MCE-funded programs operate on a fiscal year basis. Accordingly, program results are presented in alignment with each funding cycle.

Detailed information on each program is provided below the tables.

1. ENERGY EFFICIENCY
Home Energy Savings
2026 (through May):
• 130 low- or moderate-income homes upgraded
• 19 no-cost heat pumps installed
2025:
• 347 low- or moderate-income homes upgraded
• 119 no-cost heat pumps installed
• 2025 Program expenditures: $2,623,613
• Value of no-cost projects delivered to customers: $2,089,777 • Lifecycle Gross GHG Emissions Reductions: 4,753 MT/CO2e • $ per MT/CO2e: $552
Results from prior years (2019-2024):
• 1,700 single family homes upgraded
• Saved participants over 500,000 kWh and over 7,000 therms • Program expenditures 2019-2024: $9,800,000
• Customers save an average of $143 per year on energy bills Results from Richmond Rising Grant (2023-present):
• 46 homes received solar installs
• 55 homes received energy efficiency upgrades
• 47 homes received electrification upgrades
Funding CPUC ($2,8000,000 annually), California Strategic Growth Council grant ($3,000,000), Chevron grant ($35,000)
Multifamily Energy Savings
2026 (through May):
• 2 properties (138 units) under rebate reservation, including 51 HP HVAC units, 53 HPWHs, 88 induction cooktops, 3 washers, and 138 other efficiency measures. 2025:
• 424 units at 12 properties upgraded
• $3.26M in rebates distributed
• Lifecycle Gross GHG Emissions Reductions: 920 MT/CO2e • 2025 Program expenditures: $988,112
• $ per MT/CO2e: $1,073
Results from prior years (2013-2024):
• 4,700+ multifamily units upgraded
• Participants saved more than 1.4 million kWh and 108,000 therms • $666,240 in annual energy bill savings)
• Distributed nearly $1.2 million in incentive payments to customers Funding CPUC ($1,706,03 annually)
Flex Market Commercial Efficiency
2026 (through May):
• 53 projects approved for install
• Forecasted to save 2,043,000 kWh annually
• Projects forecasted to earn $671k in performance incentives 2025:
• 21 projects
• Forecasted to save 1,618,000 kWh annually (approximately $485,400 in annual energy bill savings)
• Lifecycle Gross GHG Emissions: 3,332 MT/CO2e
• 2025 Program expenditures: $1,782,376
• $ per MT/CO2e: $535
Results from prior years (2021-2024):
• Installed 103 projects that are forecasted to save over 8,650,000 kWh annually (approximately $2,595,000 in annual energy bill savings) Funding CPUC ($6,733,937 annually)
Flex Market Residential Efficiency
2026 (through May):
• 120 sites submitted for eligibility
• 33 projects completed (HPWH and HP HVAC)
2025:
• Launched in mid-2025, focusing on heat pump water heaters • 54 projects approved for installation
• Total Expenditures: $192,092
• Lifecycle Gross GHG Emissions: 213 MT/CO2e
• $ per MT/CO2e: $903
Funding CPUC ($809,783 annually)
Small Business Energy Advantage
2026 (through May):
• 60 projects completed
• 208 businesses enrolled in MCE Cares
2025:
• 167 businesses upgraded
• Average annual bill savings of $490
• Over $570,000 in incentives
• Total Expenditures: $1,260,077
• GHG Emissions Reduction methodology is still being developed for this program Results from prior years (2024):
• Provided 40 small businesses with over $135,000 in incentives to install efficient equipment Funding CPUC ($973,276 annually)
Energy Management
2026 (through May):
• Energy Coaching:
o 30 customers participating
o Forecasted savings: 1,157,574 kWh and 1,044,500 therms • Capital Projects:
o 4 projects completed (pool covers)
o 61,490 therms gas savings
o $55,892 in customer incentives
2025:
• Energy Coaching:
o 29 properties participated in forecasted to save 1,091,918 kWh and 76,440 therms (approximately $693,000 in annual bill savings)
• Capital Projects:
o 4 projects savings 25,000 kWh and 4,000 therms annually • Expenditures: $1,157,848
• Lifecycle Gross GHG Emissions Reductions: 3,853 MT/CO2e • $ per MT/CO2e: $300
Results from prior years (2016-2024):
• Energy Coaching:
o $240,000 in incentives to 12 participants
o Saved over 3.7 million kWh of electricity and over 315,000 therms annually (approximately $1,828,200 in annual energy bill savings) o 30 of MCE’s top 250 Largest Customers have participating in Energy Coaching • Capital Projects:
o Over 1,000 projects
o 13.5 million kWh and 1 million therms saved
o $5.7M in rebates awarded
Funding CPUC ($1,775,805 annually)
Green Workforce Pathways
2026 (through May):
• 2 contractor trainings in January and June 2026, with 150 contractor installer in attendance • 8 contractors provided with stipends to attend manufacturer training • 64 job seekers provided with career readiness services 2025:
• Placed 13 jobseekers with local electrification contractors in MCE's service area • 23 contractors provided with stipends to attend manufacturer training • 64 job seekers provided with career readiness services • Launched the Contractor Finder Tool on MCE’s website
• Hosted the E-Contractor Academy at MCE's Concord Offices and at the UA Local 342 JATC in Concord
o 15 participants representing 13 small, minority, women-owned construction businesses, ranging across different trades from general, electrical, plumbing to HVAC, solar and seismic engineering
• GHG emissions reductions are not tracked for this program because it is a workforce program and does not directly influence the installation of equipment Marin Community Foundation Grant:
• Launched the LIME Foundation's Next Gen Trades Academy in San Rafael • ABC7 aired a broadcast segment in January 2026
Results from prior years (2021-2024):
• Placed 48 job seekers with local electrification contractors in MCE's service area • Supported 139 job seekers in career readiness workshops Funding CPUC ($1,055,940 annually), Marin Community Foundation Grant ($380,000)

2. TRANSPORTATION ELECTRIFICATION
MCE Sync
FYE 2027 (through May):
• 3,429 vehicles with Smart Charging enabled (out of 4,823 connected vehicles) • Average year to date customer savings: $18.71
FYE 2026:
• Shifted out of peak: 773,169 kWh
• Customer savings (avg): $81.75/EV
• Customer incentives (total): $327,306.22
• Expenditures: $720,769
Chargewise Pilot:
• 522 vehicles on a Dynamic Rate with Smart Charging enabled • 98% of charging shifted out of peak periods
• 30% of charging occurred during the day (9am-3pm)
• Participants earned an average of $19/month in dynamic rate credits in addition to the average monthly savings of $11/month on their electricity bill • Participating customers have earned approximately $120,000 in dynamic rate credits Funding MCE Resiliency Fund FYE 2026 ($926,692)
EV Rebates
FYE 2027:
• Program forecast to reopen mid-July
FYE 2026:
• 1,29 7 rebates issued for EV purchase or lease using $2,718,500 in MCE rebates o 610 new vehicles ($2,135,000 in MCE rebates)
o 687 used vehicles ($1,374,000 in MCE rebates)
• Lifecycle Gross GHG Emissions Reductions: 46,692 MT/CO2e • Expenditures: $3,900,000
• $ per MT/CO2e = $84
Results from prior years (2022-2024):

EV Instant Rebates:
• 1,367 rebates for EV purchase or lease using $4,170,000 in MCE rebates o 1,007 new vehicles ($3,498,000 in MCE rebates)
o 360 used vehicles ($672,000 in MCE rebates)
EV Rebate Program (2019-2022):
• 347 rebates issued for EV purchase or lease using $1,211,000 in MCE rebates Funding MCE Local Programs Fund FY2E 2026 ($4,566,480)
EV Charging Program
FYE 2027 (through May):
• 12 new charging ports installed, 540 under reservation • $50,000 in MCE incentives provided
FYE 2026:
• 397 new charging ports installed
• $1,733,00 in MCE incentives provided (approximately 41% of project costs covered by MCE rebates)
• 126 Charging Planning Reports delivered (80% to low-income or disadvantaged communities)
• GHG Emissions Reductions are not tracked for this program because of the administrative burden of tracking charging station usage data
Results from prior years (2018-2024):
• 1,232 new charging ports installed using $2,390,000 in MCE incentives Charge up Contra Costa (2022-present):
• 92 ports installed in low-income communities in Contra Costa using $545,000 in grant funding
• 128 additional ports under construction
Funding MCE Local Programs Fund FYE 2026 ($1,710,745), CEC Grant – Charge Up Contra Costa ($1,200,000), Marin Community Foundation Grant ($180,000) Charged by Public Power
• Launched in 2024
• Collected over 600 survey responses
• Reached 131 focus group participants
• Starting project host site identification
• GHG Emissions Reductions are not tracked for this program because of the administrative burden of tracking charging station usage data
Funding DOE Grant ($1,000,000)

3. BUILDING ELECTRIFICATION
Heat Pump Water Heater Incentives
FYE 2027 (through May):
• 29 heat pump water heaters installed
FYE 2026:
• 216 heat pumps installed
• $463,570 in MCE incentives
• Lifecycle Gross GHG Emissions Reductions: 2,862 MT/CO2e • $ per MT/CO2e = $162
Results from prior Years (2022-2024):
• 600 heat pumps installed using $854,000 in MCE incentives Funding MCE Local Programs Fund FYE 2026 ($800,000)
Emergency Water Heater Loaner Program
Results 2024-2025:
• Launched in 2024, closed to new applicants at the end of 2025 • 10 heat pump water heaters installed using emergency loaners since the program • Expenditures: $15,000
• Lifecycle Gross GHG Emissions Reductions: 133 MT/CO2e • $ per MT/CO2e = $113
Funding MCE Local Programs Fund FYE 2026 ($142,000)

4. ENERGY STORAGE PROGRAM
Energy Storage for Residents and Critical Facilities
• Program closed to new applicants
Results from prior Years (2020-2024):
• 1.25 MWh of non-residential storage installed at 13 sites • 1.24 MWh of residential storage installed at 76 homes • Lifecycle Gross GHG Emissions Reductions: 4,820 MT/CO2e • Cumulative MCE Expenditures: $4,384,000
• $ per MT/CO2e = $910
Funding MCE Resiliency Fund FYE 2026 ($306,000), Marin Community Foundation Grant ($750,000), Self Generation Incentive Program Funding (>$1,000,000)
Department of Energy Storage Grant
Current program status:
• 12 applications received
• 3 sites selected for federal funding
Funding DOE Grant ($500,000), MCE Match Funding ($500,000) Solar Storage Credit
• 1,469 active customers
Funding MCE Operational Funds FYE 2026 ($250,000)
Program Participation by Community
The following tables summarize community participation by county across MCE’s customer programs.

Contra Costa County
Community Home
Energy
Savings
Multi-Family
Energy
Savings
Flex Market
Commercial
Efficiency
Small
Business
Energy
Advantage
Energy
Management
MCE
Sync
EV
Rebate
EV
Charging
Energy
Storage
Concord ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Danville ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
El Cerrito ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Hercules ✓ ✓ ✓
Lafayette ✓ ✓ ✓ ✓ ✓ ✓
Martinez ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Moraga ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Oakley ✓ ✓ ✓ ✓ ✓ ✓ ✓
Pinole ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Pittsburg ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Pleasant
Hill
✓ ✓ ✓ ✓ ✓
Richmond ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
San Pablo ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
San Ramon ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Walnut
Creek
✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Uninc.

Contra
Costa
County
✓ ✓ ✓ ✓ ✓ ✓
Marin County
Community Home
Energy
Savings
Multi-Family
Energy
Savings
Flex Market
Commercial
Efficiency
Small
Business
Energy
Advantage
Energy
Management
MCE
Sync
EV
Rebate
EV
Charging
Energy
Storage
Belvedere ✓ ✓ ✓ ✓ ✓
Corte
Madera
✓ ✓ ✓ ✓ ✓ ✓
Fairfax ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Larkspur ✓ ✓ ✓ ✓ ✓ ✓
Mill Valley ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Novato ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Ross ✓ ✓
San
Anselmo
✓ ✓ ✓ ✓ ✓ ✓ ✓
San Rafael ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Sausalito ✓ ✓ ✓ ✓ ✓ ✓ ✓
Tiburon ✓ ✓ ✓ ✓ ✓ ✓ ✓
Uninc.

Marin
County
✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Napa County
Community Home
Energy
Savings
Multi-Family
Energy
Savings
Flex Market
Commercial
Efficiency
Small
Business
Energy
Advantage
Energy
Management
MCE
Sync
EV
Rebate
EV
Charging
Energy
Storage
American
Canyon
✓ ✓ ✓ ✓ ✓ ✓ ✓
Calistoga ✓ ✓ ✓ ✓
City of
Napa
✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
St. Helena ✓ ✓ ✓ ✓ ✓
Yountville ✓ ✓ ✓ ✓
Uninc.

Napa
County
✓ ✓ ✓ ✓ ✓ ✓
Solano County
Community Home
Energy
Savings
Multi-Family
Energy
Savings
Flex Market
Commercial
Efficiency
Small
Business
Energy
Advantage
Strategic
Energy
Management
MCE
Sync
EV
Rebate
EV
Charging
Energy
Storage
Benicia ✓ ✓ ✓ ✓ ✓ ✓ ✓
Fairfield ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Vallejo ✓ ✓ ✓ ✓ ✓ ✓ ✓ ✓
Uninc.

Solano
County
✓ ✓ ✓
Detailed Program Information

1. Home Energy Savings
Description: MCE's Home Energy Savings program aims to improve the comfort, efficiency and indoor air quality of low- and moderate-income households living in single family homes. The program offers free energy assessments and education with single point-of-contact customer service and free energy-efficient and electrification measures.

The program serves homeowners and renters whose household income is 200%-400% of the Federal Poverty Guidelines. This typically exceeds the income limit for services provided by programs like PG&E’s Energy Savings Assistance program. However, income constraints often prevent this group from participating in market-rate programs.

Richmond Rising is an initiative funded by a $35M grant awarded to the City of Richmond by the Strategic Growth Council. MCE was a sub awardee for this grant to expand Home Energy Savings and the installation of rooftop solar in Richmond.

2. Multifamily Energy Savings Program
Description: MCE’s Multifamily Energy Savings program helps transform multifamily homes into healthier, more energy efficient, all-electric spaces. The program is designed to make electrification and energy upgrades easier by breaking down common barriers like high upfront costs, complex decision-making, and the technical expertise needed to get started. The program offers free energy assessments for common areas and units, support with contractor selection and project planning and rebates for in-unit and common area measure upgrades such as ENERGY STAR® appliances, efficient lighting, insulation, windows, and water fixtures, electrification upgrades including heat pumps, induction stoves, electric dryers, and panel upgrades.

3. Efficiency Flex Market
Description: MCE's Commercial Flex Market programs provide energy efficiency incentives directly to project developers or contractors known as aggregators. The incentives are based on metered energy savings, instead of traditional energy efficiency programs that utilize deemed or custom models. These programs do not limit the technology or energy saving strategies implemented, resulting in the opportunity to maximize energy efficiency and load-shifting projects. Because the incentive is paid directly to the aggregator, the value is passed along to the customer in the way that best drives the success of the project, either by reducing upfront costs or getting paid based on energy savings performance.

MCE’s Residential Flex Market was relaunched in 2025 after contractors shared that the previous incentive process made it hard to manage cash flow between project completion and the later measurement period used to calculate payments. The updated program now provides an upfront rebate at installation based on estimated savings, plus a performance bonus a year later based on the project’s actual energy savings.

4. Small Business Energy Advantage
Description: MCE's Small Business Energy Advantage program helps small businesses in underserved communities become more resilient by providing equitable access to bill-reducing energy efficient upgrades that improve health, comfort, and safety. Unlike traditional programs, MCE's Small Business Energy Advantage program focuses on businesses that have historically been overlooked, ensuring real-world impacts and lasting community benefits.

The program offers free energy assessments and tailored education for all enrolled businesses, no-cost and low-cost energy efficiency upgrades, ongoing support, including project planning, installation, and post-installation follow-up to ensure satisfaction and connect businesses to additional resources.

5. Energy Management
Description: The Energy Management program offers a long-term approach to help multifamily properties and businesses save money, earn financial incentives, and better manage their energy usage. Participants can access free onsite assessments, cohort-style training, individual coaching, and peer-to-peer learning to build a stronger energy culture within their organization. The program offers customized opportunities to change how existing equipment is used (rather than installing new equipment) so the customer can see significant bill savings with little to no-upfront cost. The Energy Management Program also offers incentives to offset the cost of capital improvement projects resulting in energy savings.

6. Green Workforce Pathways
Description: MCE’s Green Workforce Pathways program supports both residential service contractors and job seekers. With a focus in 2026 on workforce readiness in response to the Bay Area Air District Ruling 9-61
the program provides no-cost training on cutting-edge clean technologies and partnerships with key industry stakeholders. For job seekers, the program offers individualized career support services.

7. MCE Sync
Description: MCE Sync is a load-shifting app that helps EV drivers automate their EV charging at home to use the least expensive and cleanest energy on the grid. On average, 80% of EV charging happens at home, with every EV adding around 50% to a resident’s overall electricity usage. As the EV market continues to grow, the importance of smart EV charging will be even more significant.

Shifting electricity load toward lower-cost energy hours when more renewables are available bolsters grid resiliency from outages during critical periods.

In late 2024, MCE partnered with EV.Energy to launch ChargeWise, a CEC grant funded pilot. The ChargeWise Pilot deploys dynamic rates that align charging to wholesale electricity prices.

Customers who opt into this pilot can take advantage of very low daytime pricing to earn EV charging credits. The customers are provided a credit for the difference between their based electricity rate and the dynamic rate offered by the pilot.

8. EV Charging
Description: MCE’s EV Charging program provides multifamily properties and businesses with EV charging rebates, along with free technical assistance. The program offers:
• Up to $4,500 per networked Level 2 charging port plus $500 per L2 charging port for projects located in state-designated priority population areas and up to $875 per networked Level 1 charging port
• Stackable rebates with other regional EV charging programs • Technical assistance including a customized EV Charging Planning Report, which includes a site assessment, load study, available incentives, recommended vendors, and user pricing

9. Charged by Public Power
Description: MCE's Charged by Public Power program supports the planning and deployment of EV chargers and clean mobility options — such as bikeshare and carshare — in nine historically underserved communities across MCE’s service area. Priority communities include Concord, Fairfield, Napa, Pittsburg, Richmond, San Pablo, San Rafael, Unincorporated Contra Costa County, and Vallejo.

To ensure community-driven decision-making, the program established the Community Electric Transportation Council (CETC), which includes representatives from local governments, transit 1 , Bay Area Air District (BAAD) Rule 9-6, “Building Appliances”, will ban the sale of NOx emitting water heaters in 2027. The BAAD board of directors will vote on any exemptions to the rule and a start date in November 2026.
agencies, and community-based organizations. The CETC plays a key role in shaping inclusive engagement strategies, assessing transportation needs through surveys and focus groups, and informing the design and placement of EV chargers based on direct community input.

10. Electrification Incentives
Description: To help increase adoption, MCE offers rebates to contractors for each energy-efficient heat pump water heater unit they install in the home of an MCE market-rate customer and slightly higher incentives for equipment installed in low- and moderate-income homes or multifamily properties. This can be combined with other energy efficiency rebates to further reduce costs.

11. Energy Storage for Residents and Critical Facilities Description: MCE’s Energy Storage Program provided rebates, monthly bill credits and for battery energy storage systems paired with solar, in exchange for allowing MCE to discharge the battery daily from 4-9pm to manage peak loads and mitigate high energy costs. The program is currently closed to new customers, but staff are continuing to support some customers through the installation process which includes PG&E project approval (Permission to Operate) and to provide performance payments to non-residential batteries for 7 years post installation.

12. Department Of Energy (DOE) Energy Storage Grant
Description: In 2025, MCE offered a grant to our municipal customers to support the installation of storage on municipal sites funded by a DOE Energy Storage Grant that was awarded to MCE. The batteries will be used to provide resiliency and to offset peak demand.

13. Solar Storage Credit
Description: MCE offers customers with solar and storage at their home a monthly bill credit ($10- $20) in exchange for automating their battery to discharge down to a 20% reserve margin daily from 4-9 p.m., except to prepare for or during a power outage.

Recommendation:

Information only.

Program
Funding
Source
Funding
Year Equity Expenditures
GHG
reductions Number of customers served $/MTCO2E Expenditures GHG
reductions Number of customers served $/MTCO2E Expenditures GHG
reductions Number of customers served $/MTCO2E
Building Electrification $1,645,070 $1,154,178 $1,326,972 Green Workforce Pathways CPUC CY yes $613,466 n/a see CP Update for detailed impacts n/a $894,178 n/a see CP Update for detailed impacts n/a $863,402 n/a see CP Update for detailed impacts n/a MCE Electrification Rebate MCE FY yes $140,000 2,306 174 heat pumps $61 $260,000 2,160 163 heat pumps $120 $463,570 2,862 216 heat pumps $162 LIFT CPUC CY yes $891,604 27 6 properties (197 units) $33,319 Virtual Power Plant $1,128,430 $851,784 $720,769
Resiliency Program MCE FY yes $457,471 126 15 (650 kWh) $3,638 MCE Sync MCE FY $493,676 n/a 3,000 vehicles n/a $851,784 n/a 3,200 vehicles n/a $720,769 n/a 3,400 vehicles n/a Peak Flex MCE & CPUC CY $177,283 75 1,092 $2,368
Energy Efficiency $7,857,666 3198.67 $8,751,904 $8,004,118 Multifamily Energy Savings CPUC CY yes $561,642 31 9 properties (653 units) $17,955 $635,293 206 6 properties (224 units) $3,084 $988,112 920 12 properties (424 units) $1,074 Commerical (split into Efficiency Market and Small Business Energy Advantage) CPUC CY $960,812 1,011 41 projects $950 Home Energy Savings CPUC CY yes $2,180,374 98 351 homes $22,207 $3,047,960 6,816 315 homes $447 $2,623,613 4,753 347 homes $552 Efficiency Flex Market (Commercial) CPUC CY $2,875,187 972 38 projects $2,958 $2,774,846 1,317 17 projects $2,107 $1,782,376 3,332 21 projects $535 Efficiency Flex Market (Residential) CPUC CY $192,092 213 21 projects $902 Energy Management CPUC CY $873,085 1,059 7 customers $824 $2,019,197 5,704 25 customers $354 $1,157,848 3,853 33 customers $301 AIR (moved into Energy Management) CPUC CY $406,566 27 6 projects $15,170 Small Business Energy Advantage CPUC CY yes $274,607 n/a 40 businesses n/a $1,260,077 n/a 167 businesses n/a Home Energy Report
Electric Vehicles $2,098,650 $4,567,528 $6,197,906
EV Charging MCE FY $583,150 n/a 83 new ports n/a $837,578 n/a 129 new ports n/a $2,297,906 n/a 397 new ports n/a EV Rebate MCE FY yes $1,515,500 15,876 441 vehicles $95 $3,729,950 29,808 828 vehicles $125 $3,900,000 46,692 1,297 vehicles $84 Total $12,729,816 $15,325,394 $16,249,765
2023/FY23-24 2024/FY24-25 2025/FY25-26
program launched in 2024
program closed
program closed to new applicants see CP Update for detailed impacts program closed
program split into Energy Management and Small Business Energy Advantage program launched in 2025
program moved into Energy Management
1 ACCOUNTANTS’ COMPILATION REPORT
Management
Marin Clean Energy
Management is responsible for the accompanying financial statements of Marin Clean Energy (a California Joint Powers Authority), which comprise the statement of net position as of March 31, 2026, and the related statement of revenues, expenses, and changes in net position, and the statement of cash flows for the year 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.

Marin Clean Energy’s annual audited financial statements 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 Marin Clean Energy because we performed certain accounting services that impaired our independence.

Maher Accountancy
San Rafael, CA
May 20, 2026
1101 Fifth Avenue, Suite 200 San Rafael, CA 94901 415 459 1249 mahercpa.com

PRELIMINARY
Current assets
Cash and cash equivalents - unrestricted 242,125,512$
Cash equivalents - restricted for grant purposes 16,270,080 Cash equivalents - restricted for security reserve 17,581,784 Accounts receivable, net of allowance 67,894,734
Accrued revenue 29,848,870
Other receivables 18,803,237
Prepaid expenses 1,071,840
Investments 78,048,161
Deposits 8,118,905
Total current assets 479,763,123
Noncurrent assets
Investments 174,622,647
Capital assets, net of depreciation and amortization 6,189,785 Deposits 197,175
Total noncurrent assets 181,009,607
Total assets 660,772,730
Current liabilities
Accrued cost of electricity 58,692,269
Accounts payable 4,433,294
Other accrued liabilities 10,155,357
User taxes and energy surcharges due to other governments 1,341,808 Security deposits - energy suppliers 856,800
Advances from grantors 16,270,080
Total current liabilities 91,749,608
Operating Reserve Fund 70,000,000
Net position
Net investment in capital assets 6,189,785
Restricted 17,581,784
Unrestricted 475,251,553
Total net position 499,023,122$

NET POSITION

MARIN CLEAN ENERGY

STATEMENT OF NET POSITION
As of March 31, 2026
ASSETS

LIABILITIES

DEFERRED INFLOWS OF RESOURCES
See accountants' compilation report. 2

PRELIMINARY
Year-to-Date

OPERATING REVENUES
Electricity sales, net 769,566,778$
Grant revenue 11,829,585
Other revenue 739,728
Total operating revenues 782,136,091

OPERATING EXPENSES
Cost of electricity 652,516,459
Contract services 23,707,526
Staff compensation 28,475,316
Other operating expenses 16,417,632
Depreciation and amortization 228,436
Total operating expenses 721,345,369
Operating income (loss) 60,790,722

NONOPERATING REVENUES (EXPENSES)
Investment income 21,369,348
CHANGE IN NET POSITION 82,160,070
Net position at beginning of period 416,863,052
Net position at end of period 499,023,122$
Year Ended March 31, 2026

AND CHANGES IN NET POSITION

STATEMENT OF REVENUES, EXPENSES

MARIN CLEAN ENERGY
See accountants' compilation report. 3

PRELIMINARY
Year-to-Date

CASH FLOWS FROM OPERATING ACTIVITIES
Receipts from customers 782,392,543$
Receipts from grantors 6,223,908
Receipts of security deposits 18,988,991
Receipts from wholesale sales and other operating activities 23,808,994 Payments to suppliers for electricity and collateral (769,469,555) Payments for other goods and services (39,785,560)
Payments for deposits and collateral (449,563)
Payments for staff compensation (27,094,705)
Payments of taxes and surcharges to other governments (13,249,249) Net cash provided (used) by operating activities (18,634,196)

CASH FLOWS FROM CAPITAL AND RELATED

FINANCING ACTIVITIES
Payments to acquire capital assets (5,612,405)
Net cash provided (used) by capital and related
financing activities (5,612,405)

CASH FLOWS FROM INVESTING ACTIVITIES
Investment income received 23,355,477
Proceeds from sales and maturities of investments 115,447,674 Purchase of investments (65,205,163)
Net cash provided (used) by investing activities 73,597,988 Net change in cash and cash equivalents 49,351,387
Cash and cash equivalents at beginning of period 226,625,989 Cash and cash equivalents at end of period 275,977,376$ Reconciliation to the Statement of Net Position
Cash and cash equivalents - unrestricted 242,125,512$
Cash equivalents - restricted for grant purposes 16,270,080 Cash equivalents - restricted for security reserve 17,581,784 Cash and cash equivalents 275,977,376$
NONCASH INVESTING ACTIVITIES:

Change in fair value of investments (667,708)$
Change in interest receivable (1,318,421)$

STATEMENT OF CASH FLOWS

MARIN CLEAN ENERGY
Year Ended March 31, 2026
See accountants' compilation report. 4

PRELIMINARY
Operating income $ 60,790,722
Adjustments to reconcile operating income to net
cash provided (used) by operating activities
Depreciation and amortization expense 228,436
(Increase) decrease in:

Accounts receivable, net (4,178,315)
Accrued revenue 2,398,072
Other receivables 2,727,436
Prepaid expenses 1,300,744
Deposits 18,539,430
Increase (decrease) in:

Accrued cost of electricity (99,730,532)
Accounts payable 453,129
Other accrued liabilities 4,801,598
User taxes and energy surcharges due to other governments 59,430 Advances from grantors (6,024,346)
Net cash provided (used) by operating activities (18,634,196)$ Year Ended March 31, 2026

STATEMENT OF CASH FLOWS (CONTINUED)

MARIN CLEAN ENERGY

RECONCILIATION OF OPERATING INCOME TO NET

CASH PROVIDED (USED) BY OPERATING ACTIVITIES
See accountants' compilation report. 5

PRELIMINARY
Interim Financial Statements
Fiscal Year
Ended 2026
MCE Board of Directors
July 16, 2026
Financial Statements Fiscal Year Ended (FYE) 2026
The financial results shown for FYE 2026 are interim,
preliminary, and unaudited.

Balances and results may change as additional information becomes available and period-end procedures are completed.

This deck is intended for internal management / Board discussion and is intended to give your Board an idea of results.

The financial statements are not the same as the budget reports. Staff will do a budget recap later in the year to explain any deviations from the budget.

Net Position across FYE 2021 - 2026
$189 $203
$244
$404 $417
$499
$28 $14
$41
$160
$13
$82
$0
$200
$400
$600
FYE 2021 FYE 2022 FYE 2023 FYE 2024 FYE 2025 FYE 2026
Millions
Cumulative Net Position
Change in Net Position
Interim
$15M
deferred
$4.5M
deferred
$40M
deferred
Income Statement
$13
$82
$0
$300
$600
$900
FYE 2025 FYE 2026
Millions
Income Statement Summary
Total Income
Total Expenses
Change in Net Position
Operating Revenues FYE 2025 FYE 2026
Total operating revenues $816,224,799 $782,136,091
Operating Expenses
Cost of electricity 768,519,084 652,516,459
Contract services 22,184,759 23,707,526
Staff compensation 24,719,274 28,475,316
Other operating expenses 12,336,595 16,417,632
Depreciation and amortization 632,602 228,436
Total operating expenses 828,392,314 721,345,369
Operating income (loss) (12,167,515) 60,790,722
Nonoperating Revenues (Expenses)
Investment Income 25,345,052 21,369,348
Change in Net Position 13,177,537 82,160,070
Net position at the beginning of period 403,685,515 416,863,052 Net position at end of period 416,863,052 499,023,122
Figures shown assume no transfers to the Operating
Reserve Fund (ORF) yet.

Balance Sheet
Investments,
$252.7 M
Cash and
cash
equivalents -
unrestricted,
$242.1 M
Accounts
receivable &
accrued revenue,
$97.7 M
Other, $68.2 M
FYE 2026
FYE 2026
Investments $252,670,808
Cash and cash equivalents - unrestricted 242,125,512
Accounts receivable & accrued revenue 97,743,604
Other 68,232,806
Total Assets 660,772,730
Accrued cost of electricity 58,692,269
Advances from grantors 16,270,080
Other accrued liabilities 10,155,357
Other 6,631,902
Total Liabilities 91,749,608
Deferred Inflows of Resources 70,000,000
Total Net Position 499,023,122
Table and pie chart shows a condensed version of the full balance sheet Other assets include: prepaid expenses, restricted cash (~$34M), deposits, and capital assets net of depreciation
Other accrued liabilities include: accrued paid time off, payroll, benefits payable, unclaimed NEM cash-outs and other deferred revenue Other liabilities include: accounts payable, security deposits from suppliers, user taxes and energy surcharges
Days Liquidity on Hand (DLOH)
$474
$495
250
-
100
200
300
$0
$200
$400
$600
FYE 2021 FYE 2022 FYE 2023 FYE 2024 FYE 2025 FYE 2026
Millions
Days
Liquidity Target $ Actual Liquidity $ DLOH Actual 240 DLOH Target Liquidity amount is based on unrestricted cash plus
investments as shown on MCE’s balance sheet
Thank you!
mceCleanEnergy.org
[email protected]

MCE Board of DirectorsJuly 16, 2026

MCE Board of Directors
July 16, 2026