Pioneer Community Energy Board of Directors
November 20, 2025

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 11/20/2025

PERSONNEL
Offers were accepted, closing out the recruitments for the Customer Care Coordinator and Power Supply Analyst positions. Pioneer’s newest team members will be introduced at the December meeting.

We are sad to lose Paige Garcia, Programs Manager, who will be starting a new adventure with another CCA but wish her well and thank her for her contributions to Pioneer.

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) The following agreements have been conducted by the Chief Executive Officer, consistent with the authority delegated by the Board:
 Agreement with Regional Government Services for Board Clerk/Executive Assistant Staffing for a not-to-exceed of $20,000.  Agreement with NewGen Strategies and Solutions, LLC for General Regulatory Consulting Services, increasing the not-to-exceed amount by $10,000 for a new cap of $20,000.

CHIEF EXECUTIVE OFFICER POWER SUPPLY CONTRACTS EXECUTIED The following agreements have been conducted by the Chief Executive Officer, consistent with the authority delegated by the Board:

Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
Central Arizona Water Conservation District 10/16/2025 Buy Pioneer PCC3 11/1/2025 11/30/2025 $97,650 Shell Energy North America 10/30/2025 Buy Pioneer North System Flexible 1/1/2026 12/31/2026 $1,562,500 Shell Energy North America 10/30/2025 Buy Pioneer South System 6/1/2026 9/30/2026 $312,500 Shell Energy North America 10/30/2025 Buy Pioneer PCC1 1/1/2026 12/31/2026 $11,497,500 California Choice Energy Authority 10/28/2025 Sell Pioneer North System Flexible 8/1/2026 9/30/2026 $690,000 Marin Clean Energy 10/22/2025 Buy Pioneer North System 9/1/2026 9/30/2026 $40,000 Marin Clean Energy 10/22/2025 Sell Pioneer South System 9/1/2026 9/30/2026 $60,000 Agenda Item: IV-B Agenda Date: 11/20/2025

FEEDING THE FOOTHILLS
I would like to thank Calpine for selecting Feeding the Foothills as one of the recipients of their community grant and Feeding the Foothills staff as well as our Board Chair Dowdin Calivillo for attending a wonderful award ceremony and for such a good cause.

Presentations and Relevant Meetings attended by the Chief Executive Officer

1. Participated in CalCCA Weekly/Monthly Board meetings.

2. Participated in the Placer Business Alliance annual conference in Washington, DC

3. Attended the Geysers Tour

4. Participated in discussions with staff of Madera County and the City of Chowchilla regarding joining Pioneer
Agenda Item: IV-B Agenda Date: 11/20/2025

GEYSERS TOUR
I would like to thank the Calpine Team at the Geysers Campus for such a wonderful tour of their impressive facility and their professionalism and courtesy to Pioneer’s Board Members and staff. We look forward to another tour in the future.

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 11-3-25

BOARD OF

DIRECTORS
NOVEMBER 20, 2025

SPECIAL MEETING

REGULAR MEETING
3:00 PM
(Post Agenda: November 14)
DECEMBER 18, 2025

SPECIAL MEETING

PH & REGULAR MEETING
3:00 PM
(Post Agenda: December 12)
JANUARY 15, 2026

REGULAR MEETING
3:00 PM
(Post Agenda: January 9)

IN THE FUTURE
Special Meeting
Closed Session
(1)Conference with Legal Counsel
(1)Conference with Labor Negotiator
(1)Conference with Legal Counsel
(1)Conference with Labor Negotiator
Regular Meeting
3:00 PM
Consent 1a Minutes for Approval-OCT 16, 2025 Minutes for Approval-NOV 20, 2025 Minutes for Approval-DEC 18, 2025 1b RES IT Policies – part 2 (Koehn) Receive Draft Financials OCT 2025 (Koehn)
Receive Draft Financials NOV 2025
(Koehn)
RES Contract Renewal – Calpine (Koehn)
1c Modified Sponsorship Policy (Stassi) RES IT Policies – part 3 (Koehn) RES Governing Board 2026 Schedule (FEB 2026-JAN 2027) (Eckert)
2026 RES Yes Energy (Kang)
1d
1e
Presentation 2 End of Legislative Session Update
(discussion-Kang)
guest: NPA
RES JPA Amendment No. 8
(action-Eckert)
PH – RES Rates (action-Eckert)
MAY RES IRP (Integrated Resource Plan) –
(action-Kang)
Regular 3 Calpine Grant Award Presentation –
(discussion - Stassi-Vanacore)
RES Addendum No. 4 to
Implementation Plan (action-Eckert)
Annual Selection of Board Officers
(action-Eckert)
NOV-DEC RES Amendment No. 6 to CEO
Employment Agreement (GC/Board Chair)
4 MIP Update
(discussion-Kang)
Programs Year-in-Review
(discussion- Stassi-Vanacore)
Annual Appointment of ad hoc EPRC
Members (2026)
Future JPA Structure of Pioneer
5 RES Amended Line of Credit
(action-Koehn)
Power Procurement Year-in-Review
(discussion-Kang)
Update on Advertising Campaign
(discussion- Stassi-Vanacore)
Administrative Recommendations to
Pioneer’s Board Meeting
6 Receive Draft Quarterly Financials
through SEP 2025 (Koehn)
Recognition of Board Members
(action-Eckert)
Annual Financial Audit (discussion – Koehn)
7 DEC-JAN RES Rebate Program
(action-Stassi-Vanacore)
8 Presentation (discussion-Eckert)
guest: Dr. Ahmad Faruqui (in person)
General Function II Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
QTRLY Updates requested by the Board
 Strategic Plan Objectives
 Sponsorship Activity
Chief Executive Officer’s Report
QTRLY Updates requested by the Board
JAN – APR – JULY – OCT
 Strategic Plan Objectives
 Sponsorship Activity
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms FEB Celebratory Toast-Debt Free
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 11-3-25
AUDIT/FINANCE COMMITTEE TO BE SCHEDULED – DECEMBER
in-person & remote locations IN THE FUTURE
David Ring, Chair
Richard Pearl, Vice Chair
Greg Janda
Gary Petersen
o May 12, 2025 Minutes
o Rates
o Financial Audit
Selection of Officers through 2026

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE

TO BE SCHEDULED
zoom only IN THE FUTURE
Gary Petersen, Chair
Alice Dowdin Calvillo, Vice Chair
Ryan Carter
Greg Janda
Sean Lomen
o (JAN-BOARD) Annual Appointment of EPRC Members (2026) Selection of Officers through 2026

EXPANSION

AD HOC COMMITTEE

TO BE SCHEDULED
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy, Vice Chair
Suzanne Jones
Lori Parlin
o Selection of Officers through 2026
GOVERNANCE COMMITTEE TO BE SCHEDULED – NOVEMBER
in-person & remote locations IN THE FUTURE
Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o September 11, 2025 Minutes
o Administration of Meetings for Large Boards
o Governance Best Practices
Selection of Officers through 2026

COMMUNITY ADVISORY COMMITTEE

TO THE CHIEF EXECUTIVE OFFICER TO BE SCHEDULED IN THE FUTURE Meets on the 4th Wednesday
(even-numbered months)
December (date TBD)

Attachment: Legislative and Regulatory Update
Date: 11/20/2025
Legislative Affairs
• As part of Pioneer’s 2025 Legislative Policy and Platform that the Board of Directors approved, Pioneer staff have submitted letters of support for the following bills:
o AB 706 (Aguiar-Curry): This is a Pioneer-sponsored bill that would establish the FOREST and Wildfire Prevention Fund, to promote biomass utilization that contributes to California’s wildfire fuel reduction targets while providing clean firm energy to improve grid resiliency. o AB 66 (Tangipa): This bill would provide a temporary CEQA exemption, until January 1, 2032, for projects that create or improve emergency egress routes in residential areas and communities that currently lack a secondary route.
o SB 88 (Caballero): This bill would require the California Air Resources Board, CalFire, and the California Energy Commission to take specific steps to track, locate, and quantify the emissions from the burning of forest and agricultural waste. This bill aims to monetize the value of avoided emissions during biomass waste utilization processes and encourage the beneficial use of biomass residues to prevent wildfires and reduce the need for managed open pile burning.
o SB 540 (Becker): This bill would provide the California Independent System Operator (CAISO) with authority to implement the “Pathways Initiative”, which would allow CAISO to tap into a wider market of electricity sources throughout the broader Western region. Numerous studies have demonstrated that establishing a regional energy market can provide Californians with substantial cost savings, improved grid reliability, and reduced air pollution. o AB 1227 (Essayli): This bill would affirm the Governor’s State of Emergency Proclamation, issued on March 1, 2025, ordering state agencies to fast-track critical wildfire prevention projects by requiring specified state agencies to report on these expedited projects. The bill would also create a temporary CEQA exemption, until January 1, 2028, for critical fuels reduction projects conducted in communities located in high fire hazard severity zones. • Pioneer-sponsored bill, AB 706 (Aguiar-Curry), has been put on pause by the author’s office due to the delay in budget negotiations. The author’s office remains committed to advocating for funding allocation for a biomass development program, as outlined in AB 706, during the ongoing budget negotiations.
• In the final days of the legislative session, the Pathways Initiative language in SB 540 (Becker) was moved to a new bill vehicle, AB 825 (Becker, Petrie-Norris, Rivas). AB 825 did not contain the provisions of concern that Pioneer had previously opposed in SB 540, allowing the Pathways Initiative to move forward successfully. Pioneer joined a coalition of broad supporters from the energy and environmental space, including CalCCA and other CCAs, in signing onto a support letter for AB 825. • On September 19, 2025, the Governor signed a package of bills aimed at promoting energy affordability and state climate goals. The energy-related bills include:
o AB 825: This bill would enable the Pathways Initiative by authorizing CAISO to participate in a Western regional energy market.
o AB 1207: This bill extends the California Cap and Trade Program, rebranded as “Cap and Invest” beyond 2030 to 2045.
o SB 254: This is an affordability omnibus bill that has a broad range of provisions aimed at promoting energy affordability and strengthening the state’s Wildfire Fund. • As of October 13, 2025, the deadline for the Governor to sign or veto the bills on his desk, below are the final results for Pioneer’s high-priority bills for the 2025 legislative session:
o AB 706: Held in Senate policy committee
Agenda Date: 11/20/2025

o AB 825 (previously SB 540): Signed by Governor
o AB 66: Held in Senate policy committee
o SB 88: Vetoed by Governor
o AB 1227: Held in Senate appropriations committee
Regulatory Proceedings
Below is a summary table of the key terms and issues, followed by further details on activities since our last Board Meeting on a few ongoing priority Pioneer regulatory proceedings and matters. More updates will follow at future Board meetings as regulatory proceedings and matters evolve.

Key Terms
CPUC- California Public Utilities Commission CAISO- California Independent System Operator CEC- California Energy Commission OIR- Order Instituting Rulemaking/ “Proceeding” LSE- Load Serving Entity AL- Advice Letter
IOU- Investor-Owned Utility PD- Proposed Decision
ALJ- Administrative Law Judge
Proceeding Issue Pioneer Position
R.22-10-010 OIR to Implement AB 843 (2022) –
The Bioenergy Adjusting Tariff
Program (BioMAT)
Expeditiously implement AB 843 to
allow CCA access to the BioMAT
program for future subsidies for
biomass procurement
R.20-05-003 OIR to Continue Electric Integrated
Resource Planning (IRP) and
Related Procurement Processes
Advocate for procurement planning
policies that prioritize affordable
baseload resources such as biomass
energy
R.24-01-017; CEC OIR 21-RPS-02
OIR to Continue Implementation
and Administration, and Consider
Further Development, of California
Renewables Portfolio Standard
Program (RPS)
Ensure Pioneer maintains
compliance with RPS mandates and
advocate for fair inclusion of
biomass in RPS guidelines
R.23-10-011 OIR to Oversee the Resource
Adequacy (RA) Program, Consider
Program Reforms and Refinements,
and Establish Forward Resource
Adequacy Procurement Obligations
Refine the current RA Program
construct; reduce volatility of RA
prices; increase RA procurement
availability and grid reliability
A.20-02-009; A.21-03-008;
A.21-06-001; A.22-05-029;
A.24-05-009; A.25-05-011
PG&E 2019 Energy Resource
Recovery Account (ERRA)
Compliance Application; PG&E 2020
ERRA Compliance Application; 2021
ERRA Compliance Application; 2022
ERRA Compliance Application; 2023
ERRA Compliance Application; 2023
ERRA Forecast Application; 2024
ERRA Forecast Application; 2024
ERRA Compliance Application; 2025
ERRA Forecast Application; 2026
ERRA Forecast Application
Reduce the ERRA impact on the
PCIA; increase data transparency
from the IOUs
Agenda Date: 11/20/2025

R.21-03-011 OIR to Implement Provider of Last
Resort (POLR)
Limit the impacts of changes to the
Financial Security Requirement
(FSR)
R.18-12-005 Utility De-energization, Public
Safety Power Shutoffs (PSPS), and
Enhanced Powerline Safety Settings
(EPSS)
Reduce impacts of PSPS and EPSS
events; increase coordination and
communications with IOUs to
ensure public safety during de-energization; limit PSPS and EPSS impacts on CCA load scheduling
CEC 21-OIR-03; 23-LMS-01 Load Management Standards (LMS) Ensure Pioneer maintains compliance with CEC mandates and
requirements
R.25-02-005 OIR to Update and Reform Energy
Resource Recovery Account (ERRA)
and Power Charge Indifference
Adjustment (PCIA) Policies and
Processes
Advocate for ERRA and PCIA
reforms that will not result in unfair
cost shifts between bundled and
unbundled customers
R.25-09-004 OIR to Enhance Demand Response
in California
Pursue systems and processes that
support timeline CCA access to
customer interval data, ensure CCA
customers have equitable access to
demand response resources, and
ensure new policies or programs do
not encroach on CCA rate and
program autonomy
AB 843 BioMAT Implementation:
• October 20, 2022 - The OIR was opened to examine the implementation of AB 843. • November 30, 2023 - The CPUC voted to approve the revised PD, which clarified many of the issues raised in the comments on the PD, while retaining the favorable outcome for CCAs. • January 2, 2024 - The IOUs submitted their Tier 2 Als, modifying the BioMAT Tariff to incorporate CCAs. • January 29, 2024 - 60 days from the Decision- CCAs finalized two provisions with Accion for website work and a third-party administrator. In addition, CCAs submitted a revised tariff, a program participation request, a power purchase agreement, a rate schedule, and a balancing statement as part of a Tier II AL to the CPUC.
• February 1, 2024 - Tier III ALs were submitted by 4 CCAs indicating interest in participating in the BioMAT program (3CE, Pioneer, RCEA, and OCPA).
• February 23, 2024 - CalCCA submitted a 15-day extension until March 14 to meet the requirement for the central BioMAT Accion webpage and standard framework for individual CCA webpages within 90 days of the decision due to an issue raised by Accion in the third-party administrator Statement of Work that the CCAs, IOUs, and Accion are attempting to resolve.
• February 25, 2024 - RCRC submitted reply comments in support of the Joint CCAs proposal to consider extending the BioMAT program sunset date.
• March 1, 2024 - A group of CCAs (Pioneer, RCEA, 3CE, OCPA, MCE, and VCE) submitted comments in the RPS proceeding asking the CPUC to consider expediting consideration of an extension to the BioMAT program beyond 2025.
• March 5, 2024 - An agreement has been reached with Accion as the Third-Party Administrator. The agreement has been reviewed and signed by Pioneer as well as the other 3 CCAs. • March 21, 2024 - A meeting was held with CPUC staff to discuss the implementation of AB 843. Brad Hill will be moving over to the Natural Resources Agency.
• March 28, 2024 - Assembly Member Aguiar-Curry submitted a letter of support to the CPUC for the Agenda Date: 11/20/2025

extension of the BioMAT program. This letter included the support of other legislators: Senator Alvarado-Gil, Senator Dahle, Senator Talamantes Eggman, and Assembly Member Dahle. • March 28, 2024 - CalCCA submitted a third request for an extension of time for an additional 31-day extension of time (until April 29) for the central BioMAT Accion webpage and standard framework for individual CCA webpages to be completed within 90 days of the effective date of the decision. Work has been delayed pending a final agreement from all parties on revisions to the third-party administrator’s Statement of Work.
• April 4, 2024 - There was a prehearing conference to address the preliminary scope of issues in the OIR for IRP where the Joint CCAs are asking for an extension of the BioMAT program. During this conference, Scott Blaising represented the Joint CCAs and asked for 1) the CPUC to expedite the extension of the BioMAT program and 2) broadly review the program.
• May 1, 2024 - CPUC approved the joint CCAs Tier 2 Advice Letter, which approved the BioMAT standard program documentation, which included the tariff, the pro-forma power purchase agreement, program participation request forms, BioMAT program website and portal development contracts, independent third-party contracts, initial balancing account statements, and non-bypassable charge rate schedule. • Pioneer has completed the implementation implemented the BioMAT program. The website and all necessary documents for BioMAT are live.
• June 20, 2024 - The CPUC issued a Draft Resolution to approve the participating CCAs’ forecast revenue requirements, which is $0 for 2024-2025 for all participating CCAs, as no BioMAT projects are forecasted to COD before then.
• September 1, 2024 - The CPUC granted the joint CCAs’ extension request for the BioMAT application, as there are no BioMAT contracts to report on, for prudent contract management. The new deadline will be 6 months after the first BioMAT contract is executed or September 1, 2025, whichever date comes first. • January 31, 2025 - Pioneer submitted a Tier 3 AL to seek cost recovery for forecasted revenue requirements for 2026, which are $0.
• March 6, 2025 - The CPUC issued a notice to Pioneer, informing us that our Tier 3 AL, seeking cost recovery for BioMAT's forecasted revenue requirements for 2026, is suspended for review for up to 120 days, beginning March 3, 2025.
• April 7, 2025 - Pioneer filed supportive reply comments to the Bioenergy Association of California (BAC)’s Petition to Modify (PFM) CPUC Decision 20-08-043 in the 2018 RPS proceeding, regarding changes to the BioMAT program. In its PFM, BAC urged the CPUC to extend or remove the sunset date on the BioMAT program, along with other program revisions, to ensure the program can meet its statutory requirement of enabling the procurement of 250 MW of distributed generation bioenergy. Pioneer, in partnership with the Redwood Coast Energy Authority (RCEA), filed comments detailing our BioMAT project development efforts and urging the CPUC to consider expedited action on the extension of the BioMAT program, considering it is scheduled to sunset at the end of 2025. Pioneer’s comments also echoed BAC’s other requested changes to the BioMAT program, including enabling more subscriptions, improving interconnection issues, and removing cost caps for Category 3 projects using forest biomass waste. • In the weeks of August 25th and September 1st of 2025, Pioneer and RCEA conducted five ex parte meetings with the offices of commissioners assigned to the RPS proceedings, where the issue of BioMAT implementation is being considered. The purpose of the ex parte was to request that the Commission expeditiously grant a five-year extension of the BioMAT program, considering that the sunset date of December 31, 2025, is quickly approaching. In the ex parte, Pioneer and RCEA presented on the background of CCAs’ interest and involvement in BioMAT, our current efforts to implement the program, and justifications for why BioMAT should be extended. The commissioners’ offices did not explicitly address if or when the issue of BioMAT extension will be considered in the current RPS proceeding. • September 18, 2025 - The CPUC issued a PD, denying BAC’s PFM’s request to extend or remove the BioMAT sunset date, along with other suggested program revisions. In the PD, the CPUC concludes that BioMAT is a costly ratepayer program that remains underutilized despite multiple program revisions and should be set to sunset at the end of 2025, in accordance with the directive outlined in the Governor’s Executive Order N-5- 24 on Energy Affordability. Pioneer and RCEA staff met with Energy Division (ED) on September 25, 2025, Agenda Date: 11/20/2025

to discuss how CCAs’ continued interest and efforts in implementing BioMAT were considered in the rationale of the PD. ED Staff acknowledged that despite CCA’s efforts to foster relationships with potential BioMAT projects, the PD only considered the lack of program utilization in the formal BioMAT queue. Pioneer and RCEA staff will collaborate to submit joint comments to the PD on October 8, 2025, further advocating against the sunset of the BioMAT program.
• October 8, 2025 - Pioneer and RCEA (“Joint CCAs”) filed opening comments on the CPUC’s PD affirming the BioMAT sunset date of December 31, 2025. The Joint CCAs argued that the PD’s reasoning erred in multiple ways including 1) undermining AB 843 which allowed the CCAs to submit bioenergy projects for any remaining BioMAT capacity, 2) not providing a comprehensive program cost benefit analysis, 3) failing to acknowledge the policy objectives that BioMAT addresses, which are not achievable through other available procurement mechanisms/ programs, and 4) failing to develop a sufficient record to base such a consequential decision on.
• October 30, 2025: The CPUC issued the agenda decision for the PD rejecting BAC’s PFM, which takes into consideration parties’ comments, but makes no changes to the PD. The agenda decision was placed on consent, but was held until the next CPUC voting meeting on November 20, 2025.

Integrated Resource Planning:
• October 7, 2015 - The California Legislature adopted SB 350, the Clean Energy and Pollution Reduction Act of 2015, which increased the state’s greenhouse gas reduction target, requiring 50% renewable electricity procurement by 2030, and mandating a doubling of energy efficiency. To meet these goals, SB 350 ordered large utilities to develop and submit integrated resource plans (IRPs), which the CPUC will review. The IRP proceeding serves as the vehicle for the CPUC to evaluate utilities’ progress towards meeting the SB 350 goals, as well as the general planning proceeding to consider California’s long-term energy needs and electric procurement policies.
• June 24, 2021 - In Decision 21-06-035, the CPUC ordered the collective procurement of 11,500 MW of new net qualified capacity (NQC) to come online in 2023-2026. 2,000 MW NQC must come from long lead-time resources providing clean firm power or long-duration energy storage. • March 13, 2023 - In Decision 23-02-040, the CPUC ordered the collective procurement of an additional new 4,000 MW NQC in 2026-2027. The decision also extends the deadline for procurement of new long lead-time resources to 2028.
• October 7, 2024 - Pioneer filed reply comments in response to the ALJ’s ruling seeking comments on the proposed resource portfolios for the 2025-2026 Transmission Planning Process (TPP). Pioneer urged the Commission to recognize the value of biomass as a clean firm resource needed to meet reliability and renewable energy goals. Our comments ultimately recommended an increase of 0.1 GW in biomass growth in the proposed portfolio.
• January 10, 2025 - The CPUC issued the PD, transmitting electricity resource portfolios, to the CAISO for the 2025-2026 TPP. The PD failed to adopt many of the requests made by party comments, including Pioneer’s recommendation to increase biomass growth.
• January 10, 2025 - The Long Duration Energy Storage (LDES) Council filed a petition for modification (PFM), urging the CPUC to clarify that derated short-duration battery energy storage cannot be used to meet the mid-term reliability procurement obligation for long-duration storage, as ordered in Decision 21-06-035.

Pioneer does not have any derated short-duration battery energy storage resources in our portfolio that would be negatively impacted if the PFM were to go into effect. • February 10, 2025 - CalCCA responded to the LDES Council’s PFM, recommending the CPUC deny the petition due to the precise nature of the language already present in the original decision, as well as to avoid the precedent of retroactive policymaking, which would disadvantage LSEs who already made procurement decisions based on the given language.
• February 20, 2025 - The CPUC issued the final decision (D. 25-02-026), transmitting electricity resource portfolios to the CAISO for the 2025-2026 TPP, which adopted the proposed initially base case and sensitivity portfolios.
• April 29, 2025: The CPUC issued a Staff Proposal on the Reliable and Clean Power Procurement Program Agenda Date: 11/20/2025

(RCPPP), with an ALJ ruling seeking comments. RCPPP is a new proposal for a long-term procurement planning framework, intended to forecast procurement needs for achieving reliability and GHG reduction goals 10 years in advance. Pioneer staff will review and work with CalCCA to provide comments. • May 15, 2025 - CalCCA requested a deadline extension on comments to the RCPPP Staff Proposal and was granted an extension from the original deadline of June 5 to July 15. In the meantime, CPUC Staff will host two workshops to facilitate stakeholder discussion on the RCPPP proposals, which include two options for a reliability procurement framework and one option for a new GHG reduction procurement framework called the “Clean Energy Standard (CES)”. In these discussions, Pioneer will continue to advocate for programmatic changes and policies that allow us to meet state-mandated reliable clean energy goals, while limiting unnecessarily complex and costly compliance measures. • July 15, 2025 - CalCCA filed opening comments on the RCPPP Staff Proposal, supporting the development of a long-term procurement framework that considers the practical realities and constraints LSEs face in the current procurement environment (supply chain issues, interconnection delays, federal policy changes).

CalCCA supported the adoption of an RCPPP reliability framework beginning in 2029, resembling Staff Proposal’s Option I with modifications to 1) align RCPPP to the RA program using the SOD methodology, 2) establish 5-year forward showing requirements in alignment with RA processes, 3) remove the proposed buffers in favor of LSE-level risk management, 4) adopt a penalty waiver process, 5) clearly define the “good faith efforts” standards adopted in the MTR order, and 6) incorporate sufficient transactability mechanisms to prevent over-procurement. CalCCA also supported the development and adoption of the CES GHG-emissions reduction framework, based on actual energy sales, as an extension of the RPS program, beginning in 2031. CalCCA urged the CPUC to coordinate with the CEC to develop a workshop process aimed at ensuring load forecast accuracy at the hourly level by LSE. CalCCA’s reply comments further urged the CPUC to consider the constraints in the current procurement environment by rejecting party recommendations for near-term procurement orders without rigorous needs assessment, overly prescriptive RCPPP frameworks that would establish long lead time (LLT) specific requirements, enforced procurement of the preferred system portfolio (PSP), and establishing excessively high procurement requirements in forward years.
• July 21, 2025 - American Clean Power- California (ACP-CA) filed a motion to amend the current IRP scoping memo to include an additional track for expedited procurement of clean resources eligible for the expiring federal tax credits (investment tax credit/ production tax credit (ITC/ PTC)). ACP-CA’s motion suggests that this procurement be done by IOUs, with costs allocated to all LSEs through the cost allocation mechanism (CAM). Pioneer filed a response highlighting the breach in procurement autonomy afforded to CCAs under the law that the ACP-CA motion represents. Pioneer also supported CalCCA’s response, which asserts the ACP-CA motion should be rejected on the basis that it does not meet the robust needs assessment required for procurement orders, cannot substantiate its claims of customer savings, and would only serve to constrain the procurement environment further. ACP-CA replied to CalCCA’s response, claiming that “CCAs are waiting on the sidelines” and not actively seeking procurement of ITC/ PTC eligible resources, to which CalCCA filed a sur-reply requesting the CPUC dismiss ACP-CA’s reply due to its mischaracterization of CCA procurement activity, as shown through CCA solicitation data. • August 1, 2025 - CalCCA filed opening comments on the new IRP OIR, R.25-06-019, which includes recommendations to the scope and schedule of the new proceeding. CalCCA recommended that the individual LSE IRP plans should be due no earlier than February 2026 or six months after the IRP filing materials and compliance guidelines are issued.
• August 13, 2025 - The CPUC issued a PD in response to Southern California Edison’s (SCE) petition for modification (PFM), seeking a waiver for the bridge contracts requirement for MTR resources in non-peak months. SCE PFM’s argued that there is no short-term reliability need for bridge resources during non-peak months, and LSEs already demonstrate fulfillment of short-term reliability needs by meeting their month-ahead RA requirements. The CPUC’s PD recognizes that short-term reliability needs are already met through RA compliance and that the MTR bridging requirement imposes unnecessary costs on ratepayers. The PD goes beyond the relief requested by SCE by eliminating the option for LSEs to use bridge contracts as an alternative compliance mechanism for long lead time (LLT) resource requirements in the MTR orders for all months of the year. CalCCA filed opening comments, urging the CPUC to clarify the intent of the PD and reduce ambiguity by adopting SCE’s PFM with modifications to apply it to all months. CalCCA asked the Agenda Date: 11/20/2025

CPUC to confirm that adoption of the PD would mean LSEs would not be found out of compliance with their MTR obligations if they have a contract that is either delayed or has been terminated for reasons beyond their control, if they are meeting their RA requirements, and making good faith efforts to replace the contract. CalCCA also urges the CPUC to more clearly define the “good faith efforts” standard and consider alternative pathways to compliance for LLT resource delays in the current or new IRP proceeding. • September 18, 2025 - The CPUC issued a decision granting, with modifications, SCE’s PFM seeking a waiver for the bridge contracts requirement for MTR resources in non-peak months. The final decision makes many clarifications from the PD, as recommended by CalCCA. The final decision specifies that LSEs will be deemed compliant with their MTR procurement obligations if they can meet their month-ahead system RA obligations for all months in which their procurement is delayed, by the final deadline for curing any RA deficiency. The decision clarifies that this compliance pathway may be used for up to three years from the required online date of the applicable procurement requirement. The decision also clarifies that while bridge contracts will no longer be available as a compliance option, bridge contracts used before the adoption of this decision remain a valid means of compliance. Lastly, the decision commits Energy Division to bringing forward a proposal in the new IRP proceeding, R.25-06-019, to clarify the compliance and enforcement standards, including the “good faith efforts” showing requirements, as recommended by CalCCA. • September 30, 2025 - The CPUC issued an ALJ ruling seeking comments on electricity portfolios for the 2026-2027 transmission planning process (TPP) and the need for additional reliability procurement. The ruling proposes the near-term procurement of an additional 1,500 MW annually from 2029 to 2032, split among LSEs based on the same allocation methodology used in the MTR and Supplemental MTR procurement orders.
• October 22, 2025 - CalCCA filed opening comments on the ALJ ruling, seeking comments on proposed electricity portfolios for 2026-2027 TPP and near-term procurement. CalCCA recommended the CPUC consider federal policy changes and load forecast uncertainty, related to speculative data center growth, and accordingly adopt a low-load growth, low-wind scenario for the TPP base case portfolio. Additionally, CalCCA described the challenges associated with ad-hoc procurement orders, such as shifting market power and exacerbating affordability issues. If a procurement order is needed, CalCCA recommends a more cautious approach to near-term reliability, proposing a procurement order of 4,000 MW, to be enforced in two tranches with 2,000 MW in 2029-2030 and 2,000 MW in 2031-2032, with an assessment of additional need in Tranche 2 taking place in 2027. CalCCA also recommended that, if ordered, the procurement order use SOD counting, require generic-only capacity, and apply the same rules that were in effect for previous MTR orders.
• October 31, 2025 - CalCCA filed reply comments on the ALJ ruling, seeking comments on the proposed 2026-2027 TPP Portfolios and near-term procurement. CalCCA responded to 60+ parties’ comments, and reiterated its main points focused on preserving procurement autonomy and flexibility including: 1) CPUC should focus on development of RCPPP to provide more long-term procurement certainty, 2) if a procurement order is needed, adopt modified tranches, 3) if a procurement order is issued, allocate need to all LSEs not a central procurement entity, 4) adopt SCE and SDG&E's recommendations for procurement flexibility in MTR and beyond, 5) reject party recommendations for any technology or attribute specific procurement order, 6) consider necessity of energy-only resources for eligibility. • October 28, 2025 - The CPUC issued the new IRP scoping memo and ruling, setting the deadline for the subsequent IRP filing as May 5, 2026.

Renewables Portfolio Standards:
• September 12, 2002 - The Renewables Portfolio Standards (RPS) program was established in 2002, by Senate Bill (SB) 1078, with the initial requirement that 20% of electricity retail sales must be served by renewable resources by 2017. The program was accelerated in 2015 with SB 350, which mandated a 50% RPS target by 2030. In 2018, SB 100 was signed into law, which again increased the RPS target to 60% by 2030 and requires all the state’s electricity to come from carbon-free resources by 2045. The RPS proceeding at the CPUC serves as the vehicle for the CPUC to implement and administer RPS compliance rules for LSEs, including Pioneer. Concurrently, the CEC is responsible for certifying electrical generation facilities as eligible renewable energy resources and for adopting regulations to enforce RPS procurement Agenda Date: 11/20/2025

requirements.
• July 22, 2024 - Pioneer filed our Draft 2024 RPS Procurement Plan to the CPUC. • August 1, 2024 - Pioneer submitted our 2023 RPS Compliance Reporting materials to the CPUC. • November 1, 2024 - Pioneer filed comments on the CEC RPS docket, regarding the Draft 10th Edition of the RPS Eligibility Guidebook. Our comments urge the CEC to consider changes to the Guidebook that would reduce barriers to the certification of biomass facilities and burdens associated with reporting and verification. Furthermore, Pioneer recommended that the Guidebook should provide guidance to potential developers on eligible biomass conversion technologies and ensure accurate accounting of the generation from these sources.
• June 30, 2025 - Pioneer filed our 2025 RPS Procurement Plan with the CPUC, providing an overview of our procurement progress and plans to meet current and future load needs in our service territories, in accordance with the RPS mandates.

Resource Adequacy:
• May 25, 2023 - The CPUC issued a PD barring non-compliant LSEs from expansion for two calendar years following a system RA deficiency.
• June 14, 2023 - CalCCA filed comments recommending the CPUC entirely reject the PD’s restrictions on LSE expansion due to RA deficiencies and modify the RA deficiency penalty.

June 29, 2023 - The CPUC issued a decision adopting a one percent minimum threshold for RA deficiencies that would limit CCA expansions; clarifying that if an LSE “cures” its year-ahead RA deficiency in the month-ahead timeframe, the year-ahead deficiency will not be applied to the expansion requirement. • July 26, 2023 - CalCCA and CCCE filed two Applications for Rehearing (AfR) of the decision to limit CCA expansion for two years due to uncured RA deficiencies. CalCCA’s PfR cited a lack of CPUC statutory authority to limit CCA expansion, and that it gives itself new unauthorized powers to discriminate against CCAs to prevent their growth needlessly; it also asserted, that without credible evidence, the CPUC determined that addition of new CCA load would be detrimental to grid reliability, and that the decision violates the CPUC’s legal requirement to apply RA enforcement measures in a nondiscriminatory manner, not just to CCAs.
• On September 19, 2023, PG&E and SCE submitted their annual central procurement entity (CPE) reports.

PG&E is short RA for all months - up to 4,400 MW.
• October 12, 2023 - The Commission opened the new RA proceeding through OIR R.23-10-011, which proposes the scope, schedule, and administration of this subsequent RA proceeding. • November 9, 2023 - CalCCA submitted comments recommending additional scoping items for the RA proceeding, including additional refinements to the RA program for the local RA CPE, compliance and penalty structure, slice-of-day (SOD) transactability, and RA import rules. • December 14, 2023 - CPUC denied CalCCA’s request for a rehearing of the decision on RA procurement obligations and the prohibition against CCA expansion for failure to comply. • January 17, 2024 - Petition for Writ of Review prohibition of CCA expansion filed. Shell also filed a petition for somewhat different reasons. The CPUC is seeking to consolidate, as there are two filings. CalCCA did not oppose the motion.
• January 19, 2024 - Proposals due in the RA proceeding for Track 1, addressing time-sensitive issues that must be resolved for the 2025 RA compliance year. CalCCA has identified 3 major problems that the RA proposals should address: RA market scarcity, the potential exercise of market power, and removing the economic incentives not to comply. CalCCA is seeking to remove the prohibition on CCA expansion in the event of noncompliance and add the ability for the CPUC to waive penalties if CCAs can demonstrate reasonable efforts to comply that were unsuccessful. The RA proposal approved by CalCCA’s Board included a temporary waiver proposal for system and flexible RA from 2025 to 2027. Partial waivers would waive the penalty points and non-fiscal consequences, and a full waiver would also be available, waiving financial penalties under certain circumstances. A slice of the day waiver would also be available. • February 23, 2024 - There was a SOD proposal workshop was held. CalCCA is requesting a delay in SOD implementation from 2025 to 2026 due to issues with the showing and compliance tools not functioning Agenda Date: 11/20/2025

properly.
• March 22, 2024 - CalCCA submitted comments on the RA Program with regard to considering RA reforms and refinements and establishing forward RA procurement obligations. CalCCA believes the focus should be on adopting proposals that protect customers against excessive RA costs and increase RA capacity availability.
• June 6, 2024 - CalCCA filed comments on the CPUC’s RA Track 1 PD, regarding key issues with SOD implementation. CalCCA emphasized how customer affordability will be put at risk due to the hourly transactability issue and the CPUC’s refusal to delay SOD implementation or offer system RA waivers. The comments also addressed a range of other issues, including the CPUC’s insistence on using a higher-than-necessary planning reserve margin (PRM), the exclusion of existing resources in cure period extensions, restrictions on the amount of RA imports allowed, and concerns about the resource counting methodology. • June 14, 2024 - CalCCA filed comments on the Assigned Commissioner’s Scoping Memo and Ruling on Track 2, proposing an adjustment of the CPE timeline. Currently, the Commission authorizes the CPE to procure local RA until 2 months before LSEs must submit their year-ahead RA showings. This leaves LSEs with limited time to fill their shortages in response to CPE allocation. CalCCA’s proposal urges the Commission to require the CPE to provide their LSEs with their local RA allocations at least 1 year prior to their year-ahead RA filings.
• June 20, 2024 - The CPUC issued a decision to adopt local capacity requirements for 2025-2027, flexible capacity requirements for 2025, and refinements to the RA program as scoped in Track 1. The Commission maintains that the 2025 RA compliance year will be the first year for the new SOD framework, but remains open to considering hourly transactability after implementation, should any issues arise. • August 23, 2024 - CalCCA filed reply comments on the ALJ ruling modifying the Track 2 schedule, expressing concerns about the upcoming loss of load expectation (LOLE) study and how it will be used to set the PRM for SOD implementation, and the proposed changes to the CPE framework and timeline. • August 30, 2024 - The Energy Division (ED) published the revised version of its RA LOLE study, which the CPUC will use to calibrate the PRM for the 2026 SOD implementation. Based on the LOLE study, ED staff recommended the CPUC adopt a 26.5% PRM during the months of January to May and a 23.5% PRM during the months of June through December, to maintain the target reliability level of 1 day in 10 years (0.1 LOLE). This recommended PRM is much higher than the initially set 17% PRM in the 2025 SOD implementation framework.
• September 9, 2024 - CalCCA filed comments on the published RA LOLE study, urging the Commission to conduct further analysis before adopting the recommended PRM of 26.5% PRM during the months of January to May and a 23.5% PRM during the months of June through December. CalCCA cited concerns with potential study methodology flaws and significant impacts to ratepayer affordability associated with the recommended PRM.
• September 19, 2024 - PG&E released its 2024 CPE Annual Compliance Report. The report indicates that they are short in their centralized procurement of RA for the next 3 years. • October 29, 2024 - The CPUC issued a PD for RA Track 2, which addresses the PRM and CPE framework.

Regarding the proposed PRM, the Commission agreed that additional vetting and further analysis are necessary, authorizing ED to undertake a revised analysis of the 2026 PRM, which will be considered in Track 3 of the proceeding. Regarding the CPE framework, the Commission successfully adopted CalCCA’s proposal to lock in CPE allocations one year earlier, providing LSEs with more time to self-procure, along with various other revisions.
• November 18, 2024 - CalCCA filed comments on the RA Track 2 PD, recommending that the CPUC recognize the significant impact that changes to the PRM can have on reliability and affordability, and allow for earlier adoption of the 2026 PRM if thorough analysis is completed by all relevant stakeholders in advance of the Track 3 timeline. CalCCA also urged the CPUC to adopt revisions to the CPE framework as outlined in the PD, with an opportunity to review their effectiveness at the end of 2027. • December 20, 2024 - ED published another revised version of their RA LOLE study, recommending an updated 2026 PRM of 21% for the months of October to May and 22.5% for the months of June to September. Due to affordability concerns, ED also included two proposals to mitigate the adverse effects of Agenda Date: 11/20/2025

the high PRMs. The first proposal entails adopting a 17% PRM as an RA requirement, paired with an effective PRM of 22.5% which only IOUs are required to comply with; this proposal would extend the current 2025 status quo. The second proposal entails adopting a 22.5% PRM, with an option for LSEs to apply for temporary System Waivers in peak months (June to September) for requirements exceeding a 17% PRM, based on a cost threshold.
• January 17, 2025 - CalCCA filed its RA Track 3 proposals, recommending the CPUC to allow LSEs to transact load obligations on an hourly basis, address co-located generation and RA needs, and incorporate the local RA CPE data request process into the existing RA filing rather than the IRP data collection process. • February 25, 2025 - ED issued a correction to their LOLE study, updating their recommended 2026 PRM to 20% for the months of November to May (off-peak) and 21% for the months of June to October (peak).

Under this new PRM, the two price mitigation proposals change accordingly. Proposal A entails adopting a 17% PRM as an RA requirement, paired with an effective PRM of 21% in the peak months of June through October, which only IOUs are required to comply with; this proposal would extend the current 2025 status quo. Proposal B entails adopting a 20% PRM for off-peak months and a 21% PRM for peak months, paired with an option for LSEs to apply for temporary System Waivers in peak months for requirements exceeding a 17% PRM, based on a cost threshold.
• February 28, 2025 - The CalCCA Board voted to support Proposal B, which would require LSEs to adopt an increased PRM of 20% in the off-peak months and a 21% PRM in the peak months, with the option of applying for a System Waiver in the peak months for obligations above a 17% PRM. • March 3, 2025- Opening comments were filed on the RA Track 3 Proposals. Most parties, except the IOUs, supported CalCCA’s proposals to adopt hourly load transactability and allow co-located energy-only resources to count as RA under SOD. Furthermore, most parties opposed Proposal B, which would have allowed for System RA waivers, and instead recommended the adoption of a PRM that would enable the grid to meet the predetermined target of 0.1 LOLE consistently. • March 17, 2025 - Reply comments were filed on the RA Track 3 Proposals. CalCCA urged the CPUC to reject arguments made by PG&E, SDG&E, and Middle River Power regarding the hourly transactability proposal. As for the proposed PRM and price mitigation proposals, CalCCA reasserted that the CPUC should adopt a 21% PRM in peak months, 20% PRM in off-peak months, along with a system RA waiver option in peak months for obligations above a 15.5% PRM, as indicated by SCE’s independent PRM study. However, due to the ongoing disputes over a correct PRM to meet the 0.1 LOLE target, CalCCA urges the CPUC to continue refining its LOLE modeling for the upcoming 2027 PRM.
• April 16, 2025 - CalCCA held ex-partes with CPUC Commissioners to continue advocating for adoption of the hourly load obligation trading proposal, setting the PRM at 21% in peak months and 20% in off-peak months with an option for system RA waiver for requirements above 15.5% consistent with Southern California Edison’s modeling results, and enabling increased co-located resource RA participation under the RA slice-of-day framework.
• May 22, 2025 - The CPUC issued a PD adopting local capacity obligations for 2026-2028, flexible capacity obligations for 2026, and program refinements as proposed in Track 3 of the RA proceeding. Regarding the PRM proposals, the PD adopts an 18% binding PRM, with an extension of the effective PRM target from 3-

5.5% for June to October, for the 2026 RA year. The effective PRM procurement target will be divided between the three IOUs based on the approximate CAISO load share. As for CalCCA’s proposals, the PD does not adopt hourly load obligation trading. Instead, the PD directs the ED to evaluate the situation after a full year of SOD implementation to assess the need, benefits, and feasibility of an hourly load obligation trading mechanism by Q2 2026.
• June 11, 2025 - Pioneer collaborated with Central Coast Community Energy (3CE) to file opening comments on the RA Track 3 PD, urging the Commission to reduce the effective PRM target from 3-5.5% to 3%, which, when paired with the binding 18% PRM, is more in line with ED’s recommended total PRM of 21%. The comments also urge the Commission to reconsider adopting CalCCA’s hourly load transactability proposal, given the abundance of supporting evidence on the record regarding its potential for widespread affordability benefits. In reply comments filed on June 16, 2025, multiple parties echoed Pioneer and 3CE’s argument for reducing the effective PRM target, to not exceed ED’s recommended PRM, based on intensive Agenda Date: 11/20/2025

modeling/ study results.
• June 27, 2025 - The RA Track 3 final decision was approved at the CPUC voting meeting. The final decision did not incorporate the changes to the PRM or adoption of the hourly load transactability proposal as requested by Pioneer and 3CE in our opening comments to the PD. • September 19, 2025 - PG&E released its 2025 CPE Annual Compliance Report. The report found that the PG&E CPE has “not been able to procure enough capacity to meet the needs in all months for any of the seven (7) local capacity areas within its territory and will be deferring procurement to CAISO backstop mechanisms for those areas for a majority of the months of the 2026 and 2027 compliance years”.

October 15, 2025 - The CPUC issued a new RA OIR, 25-10-003, to continue overseeing RA procurement obligations for LSEs beginning with the 2027 compliance year and to consider structural reforms to the program. CalCCA filed opening comments on November 4, 2025 recommending the CPUC consider the following items in the proceeding’s scope: 1) RA hourly load transactability proposal, 2) load forecasting issues, 3) clarifying intended use of the RA data request responses in CPE procurement decisions, 4) updates to MIC showing requirements to align with SOD framework, 5) consideration of demand response, distributed energy resources, and microgrid accreditation.

PG&E ERRA Compliance and ERRA Forecast:
• The ERRA proceedings act as a review of an IOU’s prior year portfolio management and accounting and seek to identify errors and discrepancies between PG&E’s revenue requirements vis-à-vis collected revenues through the IOUs’ General Rate Case (GRC), which ultimately affects CCA rates through the Power Charge Indifference Adjustment (PCIA).
• May 14, 2023 - PG&E’s 2023 – 2024 ERRA Forecast and Testimony was released. • June 1, 2023 - NewGen sent over the new rate forecast spreadsheet. The forecast appears promising, with the PCIA remaining negative across many vintages; however, this is expected to change before the October Update.
• June 16, 2023 - Keyes and Fox filed a Protest to PG&E's Forecast Application. • August 10, 2023 - CalCCA filed a Protest to PG&E’s ERRA Trigger Application proposing a rate increase in November to correct and account for under-collections.
• September 6, 2023 - CalCCA provided Testimony on the 2024 PG&E ERRA Forecast case and touched upon the fixed generation cost issue.
• October 16, 2023 - PG&E’s October Update to its 2024 ERRA Forecast came out. Energy prices have softened relative to PG&E’s original forecast (which would, all else equal, cause PCIA rates to increase). Still, RA and RPS benchmarks have increased significantly since PG&E's filing (dampening the impact of energy prices). All told, forecast rates increased relative to the original forecast across the board, but forecast rates remain negative for vintages 2021 and later.
• November 1, 2023 - Keyes and Fox submitted comments on PG&E’s ERRA Trigger proposal and comments on PG&E’s October update.
• November 16, 2023 - The CPUC unanimously approved the Alternate PD and indicated that “the decision balances a myriad of competing interests- affordability, feasibility, safety, and reliability.” PG&E requested $15.4 billion for 2023, and the decision reduced that amount by $1.8 billion to $13.5 billion. This is an 11% increase from the authorized 2022 revenue requirement. For the typical residential customer, their combined monthly electric and natural gas bill will increase by $32.62, or 12.8%, compared to PG&E’s request of $38.73, or a 17.9% increase.
• November 30, 2023 - The PD for the PG&E 2024 ERRA Forecast was released. There were a couple of disputed issues, including whether to amortize the 2023 trigger balance over 6 months or 12. CalCCA was asking for 12, and PG&E was asking for 6 months. The CPUC adopted PG&E’s recommendation. The second issue was whether PG&E should apply a first-in, first-out (FIFO) methodology to the use of excess prior-year RECs or a last-in, first-out (LIFO) methodology. The CPUC ruled in favor of PG&E on a last-in-first-out methodology.
• December 12, 2023 - A revision to the PD came out, and CalCCA won its argument on first-in-first-out, meaning the CPUC is requiring PG&E to use a first-in-first-out methodology for RECs banked in or after 2019.

Agenda Date: 11/20/2025

• December 29, 2023 - PG&E submitted its Annual True-Up to change PG&E’s electric rates on January 1, 2024.
• March 21, 2024 - There was a Preliminary Issue Review with Keyes and Fox. The 2021 ERRA proceeding is still open but is coming to a close. 2022 is still busy, and 2023 is just getting started. Some of the big issues to watch include PG&E’s RA Sales and Accounting; DWR reimbursement to PG&E; and Retained, Sold and Unsold RPS.
• June 12, 2024 - The Assigned Commissioner issued the Scope Ruling in PG&E’s 2023 ERRA Compliance proceeding. The ruling does not adopt CalCCA’s recommendation to expressly clarify that the reasonableness of PG&E’s record year RA activities and sales is within the scope of this proceeding. It excludes the RA scoping issue from this proceeding altogether, possibly in hopes that the issue will be settled in PG&E’s 2022 ERRA Compliance proceeding. The Scope Ruling also lays out the procedural schedule. NewGen and Keyes & Fox will continue to work on discovery and reconvene with CalCCA before Intervenor testimony is due in September.
• June 17, 2024 - CalCCA filed a protest to PG&E’s 2025 ERRA Forecast application. In this proceeding, the 2025 levels for the PCIA will be established. Due to forecasted low brown energy prices and high RA prices, the PCIA is expected to decrease, resulting in increased generation rates for PG&E’s bundled customers.

PG&E’s 2025 ERRA Forecast application proposes a new ratemaking method to ensure reasonable rates for bundled ratepayers by freezing the RA market price benchmark (MPB) at its 2024 forecast level, rather than using the 2025 forecast or the 2024 actual RA MPBs. CalCCA responded, urging the Commission not to consider these broad policy questions, which fall outside the scope of the ERRA Forecast proceeding. CalCCA also argues that implementing a RA value cap would inappropriately inflate PCIA rates, shifting costs to unbundled customers, thereby violating the PCIA ratemaking framework that has been established. • July 25, 2024 - The CPUC issued an ALJ ruling in PG&E’s 2022 ERRA Compliance proceeding, reopening discovery to examine potential RA withholding actions taken by PG&E. • August 1, 2024 - Assigned Commissioner issued a Scoping Memo and Ruling in PG&E’s 2025 ERRA Forecast application, supporting CalCCA’s protest that this proceeding is not the correct venue to address the RA MPB issue.
• September 3, 2024 - CalCCA filed a direct testimony, prepared by Brian Dickman, in PG&E’s 2025 ERRA Forecast proceeding on behalf of CCAs. The testimony urges the CPUC to reject PG&E’s proposed change to its common cost allocation method and its proposal to create a new category of RPS-eligible resources outside of the previously recognized context of the PCIA calculation. The testimony also calls upon PG&E to make corrections to its calculation of “negative retained system RA” and “amount included as the amortization of the gain on the sale of its San Francisco General Office headquarters”. • October 4, 2024 - CalCCA filed an opening brief, prepared by Keyes and Fox, in PG&E’s 2022 ERRA Compliance proceeding regarding the issue of PG&E withholding excess RA. CalCCA urged the Commission to revisit PG&E’s Bundled Procurement Plan in the IRP proceeding to ensure PG&E is making its excess RA available to the market in a timely and comprehensive manner, which is critical due to current RA market shortages. The brief incorporated the discovery responses received from PG&E, once the ALJ reopened the discovery window for CalCCA in July 2024.
• October 4, 2024 - The Energy Division released the 2024 Final MPBs and 2025 Forecast MPBs, which are used to calculate the PCIA in PG&E’s 2025 ERRA Forecast proceeding. They have since issued corrections to the MPBs several times.
• October 8, 2024 - In the PG&E 2025 ERRA Forecast proceeding, the ALJ issued an email ruling requesting comments on the impact of the recently released MPBs. The questions posed ask parties whether they expect the released MPBs to have a significant impact on the issues within the scope of the proceeding, and to offer any procedural options to address these impacts. • October 14, 2024 - PG&E and CalCCA replied to the ALJ's ruling, requesting party comments regarding the impact of the released MPBs. PG&E stated that the released RA MPBs will result in a $500 million increase to the bundled customer-generated revenue requirement. In comparison, departing load customers would see a net reduction of $500 million through their PCIA. Furthermore, the released RPS MPB would increase the bundled service customer generation revenue requirement by an additional $250 million, with a Agenda Date: 11/20/2025

corresponding reduction to departed load customers. For these reasons, PG&E requests that the Commission delay the procedural timeline and consider various mitigation methods, such as developing additional rate-setting scenarios and establishing a tracking account to mitigate any potential cost shifts while further investigating this issue. CalCCA stated in their replies that the RA MPB is operating as the Commission intended; therefore, no modifications to the ratemaking process in this proceeding are warranted. CalCCA reiterated that proposals to modify the PCIA revenue requirement calculation methodology are outside the scope of this proceeding and should not be considered in response to the ALJ ruling. • October 23, 2024 - PG&E filed its Fall Update, in which it argues that the recently released MPBs were wrongly calculated and inflated. Considering how the high price of the RA MPB does not appropriately incentivize procurement compliance, PG&E urges the Commission to consider mitigation measures. They present various mitigation proposals that involve freezing the RA and/or RPS MPBs at 2024 forecast levels and tracking the differences in a balancing account.
• October 31, 2024 - CalCCA filed a motion to strike PG&E’s MPB discussion and mitigation proposals from the record, as they were already deemed out of scope for this proceeding in a previous ALJ ruling. CalCCA also filed a reply brief, which reiterates that the Commission should not consider MPB mitigation measures in this proceeding and argues that the “gross revenue requirement” methodology equitably allocates common costs to customers.
• November 15, 2024 - CalCCA held an ex parte meeting with Maria Sotero from Commissioner Reynold’s office to discuss the MPB issues and better understand the strategies the CPUC intends to pursue in this case. The CPUC expressed understanding of CalCCA’s recommendation to maintain consistent usage of the MPB methodology in PG&E’s 2025 ERRA Forecast proceeding but did indicate a desire to open a new rulemaking to consider changes to the MPB methodology.
• November 15, 2024 - PG&E submitted its Annual Electric True-Up to adjust PG&E’s electric rates effective January 1, 2025.
• November 25, 2024 - The CPUC issued a PD for the PG&E 2025 ERRA Forecast proceeding, which maintained that PG&E’s RA mitigation proposal is out of scope, securing CalCCA’s win in preventing $1B in costs to the PCIA. PG&E was ordered to use the 2024 MPBs that ED released. However, the PD states that the CPUC may open a new rulemaking to consider modifications to MPB methodology, with possible retroactive rate collections in PG&E’s 2025 Annual Electric True-Up. Furthermore, the PD adopts PG&E’s common cost allocation proposal but sides with CalCCA, arguing that the change should be applied prospectively, starting in 2025, not to 2024 costs.
• December 2, 2024 - CalCCA filed opening comments to the PD in PG&E’s 2025 ERRA Forecast proceeding, emphasizing the importance of providing adequate timelines and discovery rights for non-IOU parties in any future proceeding that will deal with modifications to the RA MPB methodology. Considering recent changes in the RA market, including System RA scarcity and sharp price increases in short-term RA, CalCCA does not oppose revisiting the RA MPB methodology, but urges the Commission to consider a more comprehensive evaluation of the methodology. CalCCA’s comments also push back on the CPUC’s adoption of PG&E’s common cost allocation methodology and urge the CPUC to instead adopt CalCCA’s proposal based on gross revenue requirements.
• December 19, 2024 - The CPUC issued a final decision in PG&E’s 2025 ERRA Forecast proceeding, bringing the proceeding to a close. The decision adopts PG&E’s revised proposal for allocating common costs, effective January 1, 2025, for rates. PG&E’s estimated 12-month net revenue requirement for 2025 is $2.25 billion, resulting in an expected 2% decrease in rates for bundled residential customers and a 4.4% decrease in rates for unbundled residential customers.
• December 30, 2024- PG&E filed its final Annual Electric True-Up, reflecting the CPUC’s final decision, to update its electric rates effective January 1, 2025.
• February 3, 2025 - CalCCA filed an opening brief in the PG&E 2024 ERRA Forecast proceeding recommending that the CPUC should not modify the definition of fixed generation costs, with which most other parties were in consensus. CalCCA also encouraged the CPUC to address any changes in the common cost allocation methodology in a separate, non-expedited rulemaking involving all three IOUs as parties, to ensure consistency in their practices.

Agenda Date: 11/20/2025

• February 28, 2025 - PG&E filed its 2024 ERRA Compliance Application. ERRA Compliance proceedings review PG&E’s activities in the prior year related to its ERRA and PCIA to ensure that those activities were reasonable and comply with Commission decisions and that associated accounts are accurate. • April 4, 2025 – CalCCA filed a Protest of PG&E’s 2024 ERRA Compliance Application, arguing that the Commission should set the matter for hearing to provide CalCCA an opportunity to analyze the application, including preliminary issues it identified concerning PG&E’s RA sales activities, PG&E contract amendments, changes to PG&E’s Retained RA Tracker, and PG&E’s treatment of “banked” renewable energy credits to meet its Renewable Portfolio Standard (RPS) requirement. CalCCA also argues that the Commission should explicitly include PG&E’s attempts to sell excess RA consistent with its Bundled Procurement Plan in 2024 within the scope of the proceeding.
• April 23, 2025 – The ALJ issued a PD in PG&E’s 2022 ERRA Compliance proceeding that found that issues concerning PG&E's sales or attempts to sell excess RA during the summer of 2022 are not relevant to issues in the proceeding. CalCCA will file comments on the PD, pushing back on this finding, given that the ERRA Compliance proceedings are the only venue we have to examine PG&E’s excess RA transactions. • May 2, 2025 – The ALJ in PG&E’s 2024 ERRA Compliance proceeding issued a scoping ruling that included CalCCA's request to include as an issue whether PG&E made reasonable attempts to sell excess RA consistent with its Bundled Procurement Plan. This Scoping Ruling conflicts with the 2022 ERRA Compliance PD, providing support for CalCCA’s arguments in comments on that PD. • May 15, 2025 – PG&E filed its 2026 ERRA Forecast application, which will, in part, establish the PCIA rate for 2026.
• June 11, 2025 – Keyes & Fox and NewGen convened a preliminary issue review regarding the PG&E 2026 ERRA Forecast application. From NewGen’s initial analysis, it is apparent that there will be a significant under-collection for the Portfolio Allocation Balancing Account, which will have to be recovered through the 2026 PCIA, putting upward pressure on that rate. There are other issues that Keyes & Fox will litigate to potentially help ease the PCIA rate increase in 2026 (e.g., battery RA valuation, use of banked RECs, PG&E’s GHG-free sales, etc.), but even if successful, that increase is expected to be significant. • June 18, 2025 – CalCCA filed a protest of PG&E’s 2026 ERRA forecast. The protest highlighted the issues discussed in the June 11, 2025, preliminary issues review regarding PG&E’s valuation of both pre-2019 banked RECs and the RA attributable to batteries in its PCIA portfolio. PG&E effectively values both at zero, which has the effect of increasing the PCIA.
• September 2, 2025 – CalCCA filed testimony in PG&E’s 2026 ERRA Forecast proceeding. The testimony provided detailed information on the two issues identified in CalCCA’s protest regarding pre-2019 banked RECs and the valuation of RA attributes of battery storage, arguing that PG&E’s approach does not properly compensate unbundled customers for the value of resources procured on their behalf. • September 15, 2025- CalCCA filed intervenor testimony in PG&E’s 2024 ERRA Compliance case, proposing that PG&E file Supplemental Testimony to correct the amount of Retained and Unsold RA and the associated credit to their Portfolio Allocation Balancing Account (PABA). PG&E’s bundled procurement plan (BPP) establishes that RA held from the market for Operational Constraints should be valued as Retained RA.

However, CalCCA found that some of this RA was valued as Unsold RA, which gets valued at zero, leading to a lower credit to the PABA and an increase to the PCIA. CalCCA proposes PG&E file Supplemental Testimony to correct this error and to credit the PABA associated with valuing the RA withheld for Operational Constraints as Retained RA.
• October 1, 2025 - The CPUC released the 2025 MPB values for the PCIA Forecast and True-Up, which the IOUs will use in their 2026 ERRA Forecast Updates set to be released October 15, 2025. The 2025 MPB calculations incorporate the changes that were made to the RA MPB methodology in the PCIA Track 1 decision. For RA, the 2025 System Forecast was $42.54/kW-mo., the 2025 Actual is $11.21, and the 2026 Forecast is $11.53. The steep decline in the 2025 actual value compared to the 2025 forecast will create substantial upward pressure on the PCIA adder for unbundled customers. For RPS, the 2025 System Forecast was $71.24/MWh, the 2025 Actual is $63.86, and the 2026 Forecast is $62.45. For 2026 Forecast Energy Index: PG&E on peak is $50.20/MWh and off peak is $52.31/Mwh. The 2025 Forecast indices for PG&E were at their peak of $55.02/MWh and off-peak of $53.18/MWh. • October 15, 2025 - PG&E submitted its October Update Testimony incorporating the PCIA MPBs that Energy Agenda Date: 11/20/2025

Division published on October 1, 2025. The 2025 Final MPBs and the updated 2026 Forecast MPBs lead to a significant PG&E PCIA rate increase.
• October 24, 2025 - CalCCA filed an Opening Brief recommending the CPUC reject PG&E’s proposal for valuing pre-2019 banked RECs used for compliance in 2026 at zero and PG&E’s proposal to adjust its RA counting for the new RA Slice of Day framework. The Brief includes arguments recommending the CPUC approve CalCCA’s application for rehearing in the PCIA proceeding on retroactive ratemaking and subsequently order PG&E to update its PCIA RA forecast to use the original RA MPB methodology to produce the 2025 Final RA MPB.
• November 3, 2025 - CalCCA filed a Reply Brief rebutting PG&E’s argument against CalCCA’s proposal to value pre-2019 banked RECs at the current RPS MPB and responding to PG&E’s arguments to support their revised RA SOD proposal. Additionally, CalCCA argues that the new RA MPB methodology should not be used to calculate the Final 2025 RA MPB, as that would constitute prohibited retroactive ratemaking. • November 10, 2025 - CalCCA submitted comments on PG&E's October Update. The comments hit on the same issues raised throughout the proceeding, but focus more on the story regarding the burden the PCIA will place on unbundled customers in 2026.

Provider of Last Resort (POLR):
• October 2, 2019 - SB 520 passed, requiring the establishment of a POLR. As part of the proceeding to implement SB 520, the CPUC is seeking to establish new policies to plan for and prevent catastrophic failures in the event of an unplanned return en masse of CCA customers to IOU service. Additionally, the CPUC will review and update existing procedures and policies for Financial Security Requirements (FSR), re-entry fees, the LSE de-registration process, and compliance requirements. • July 31, 2023 - CalCCA's Reply Briefs were submitted and addressed PG&E’s proposal to modify the FSR to reflect two months of forecast energy costs, other parties’ recommendations on elements of the existing FSR calculation, mandatory contract assignments, financial monitoring, and the duration of POLR service. • March 14, 2024 - The CPUC issued a PD, with a mix of favorable and unfavorable decisions. For example, it rejected PG&E’s proposal to require FSR postings to reflect 2 months of POLR service, maintains the ability to use service bonds, and keeps confidential the information about LSEs that trigger financial monitoring.

However, the PD also approved using PG&E’s Administrative Fee ($4.24) without sufficient evidence of the costs. The CPUC should clarify that the November 2024 FSR calculation will be the earliest possible calculation under the new rules. Additionally, the CPUC should clarify the timing of the second tier of reporting requirements so CCAs know when to evaluate their metrics. The biggest issue the PD addressed was updating the FSR requirements. The minimum FSR remains $147,000, but now CCAs must use the IOU’s Administrative Fee multiplied by the number of accounts the CCA has, and post whichever amount is higher. For CCAs in PG&E’s territory, the administrative fee is $4.24 per customer, whereas the administrative fees of the other IOUs are significantly lower (around $0.50 per customer). If the final decision requires CCAs within PG&E’s service territory to use PG&E’s administrative fee, all CCAs within PG&E’s service territory will likely be paying an FSR well over the $147,000 minimum. • April 23, 2024 - CPUC adopted a revised POLR Decision inclusive of several of CalCCA’s requests.

Specifically:
o Reducing RA costs in the FSR by accounting for returning CPE RA allocations, in addition to the CAM and DR RA allocations.
o Nets PCIA in the FSR, whether the PCIA is positive or negative. o Affirms current timing for calculating FSRs.
o Provides CCAs with an additional 60 days to file the first FSR following the implementation of the IOU tariffs.
o Requires CCAs to file the Tier 1 audited financial report to the Energy Division once a year, in January or July, whichever comes earlier relative to the availability of the audited financial statement.
o Allows 90 days for CCAs to submit a joint advice letter on the new CCA registration process • July 12, 2024 - CalCCA, on behalf of Pioneer, filed a Tier 2 AL to formalize the Financial Monitoring and Reporting Guidance document. The CPUC requires financial reporting to be done on a 2-tier system. Tier 1 requires every CCA to submit an annual audited financial report. Tier 2 requires CCAs to submit additional Agenda Date: 11/20/2025

financial reporting if certain trigger events occur, such as a change in credit rating. This document clarifies the process and procedures CCAs must follow to comply with Tier 2 financial reporting conditions. o July 22, 2024 - The joint IOUs filed a protest to the joint CCAs’ AL on Financial Monitoring and Reporting Guidance, insisting CCAs’ use “lines of credit” instead of “letters of credit” as the primary financial instrument to demonstrate days of liquidity on hand (DLOH). The IOUs also insisted that CCAs report financial triggers 10 days after they occur, instead of the proposed 60 days.
o September 6, 2024 - CalCCA met with Energy Division to express that CCAs agree to comply with the joint IOUs’ request to use “lines of credit” to calculate DLOH. Regarding the minimum number of days required to report financial trigger events, CCAs insist on maintaining 60 days, as this is the minimum amount of time necessary to prepare accurate financial statements due to the complexity of their billing and accounting systems. • July 17, 2024 - CalCCA, on behalf of Pioneer, filed a Tier 2 AL to clarify requirements for the new CCA registration process and implementation plan. These requirements include (1) submission of a feasibility study and pro forma financial statement with the Implementation Plan, (2) establishment of annual assumptions to be included in the pro forma financial statement, (3) establishment of milestones for critical implementation action and review progress, and (4) submission of an updated pro forma financial statement six months before launch. The AL served to provide additional examples for annual assumptions and critical milestones.
o August 6, 2024- PG&E filed a protest to the joint CCAs’ AL on additional implementation plan requirements, citing that the proposal would limit the CPUC’s ability to assess whether enhancements to the implementation plan would result in cost shifts to bundled customers. o August 13, 2024- CalCCA filed a reply to PG&E’s protest on the additional implementation plan requirements, citing that the additional requirements proposed are correctly slotted under the umbrella of CPUC authority to certify implementation plans and determine a cost-recovery mechanism for CCA customers that prevents cost shifts to bundled customers. • August 6, 2024 - An ALJ Ruling was issued to define the scoping issues in Phase 2 of the POLR proceeding, which will be primarily concerned with clarifying requirements for an application for a non-IOU LSE to become the POLR.
• August 23, 2024 - The prehearing conference for Phase 2 was held, in which CalCCA filed a statement agreeing with the current set of questions proposed in the Phase 2 scope. In its statement, CalCCA also urged the CPUC to reject PG&E’s request to scope in issues regarding the liquidity needs of the POLR and analysis of seasonal RA pricing.
• October 24, 2024 - The CPUC issued a scoping ruling for Phase 2 of the POLR proceeding, which identifies two primary topic areas. The first is establishing the regulatory framework for non-IOU POLRs, and the second is the development of the joint application for a non-IOU LSE to serve as POLR. • November 12, 2024 - The IOUs filed their ALs for the bi-annual FSR updates. CalCCA compiled the IOU ALs and confirmed they all made their FSR calculations consistent with the current authorization. Given that the IOU ALs implementing Phase 1 are still pending resolution, the FSR updates utilize the existing methodology without the Phase 1 Decision modifications. Due to the hold on the ALs, all CCAs will be required to post the minimum FSR of $147,000 as of January 1, 2025.
• November 26, 2024 - The CalCCA Regulatory Committee voted in favor of CalCCA engaging in Phase 2 of the POLR proceeding on behalf of its members, to ensure CCAs have a voice in the discussion for how a non-IOU POLR will be established and regulated. CalCCA will present the results of the Regulatory Committee’s vote to the Executive Committee on December 3, 2024, and to the CalCCA Board on December 12, 2024.
• December 12, 2024 - CalCCA’s Board of Directors voted to engage in Phase 2 of the POLR proceeding. • January 10, 2025- Opening comments were filed on the CPUC’s Phase 2 threshold questions. No IOUs expressed interest in transferring their POLR responsibilities. However, all three IOUs argued that any non-IOU LSE that serves as POLR should be subject to full CPUC jurisdictional authority. Furthermore, no non-IOU LSEs expressed interest in becoming the POLR, except for Shell Energy, which only wants to serve commercial and industrial customers.

Agenda Date: 11/20/2025

• January 24, 2025 - CalCCA filed reply comments on the CPUC’s Phase 2 threshold questions, recommending the CPUC to establish a core framework for non-IOU LSE requirements and a joint application process, but stopping short of building out the entirety of the framework due to the current lack of interest by parties in the designated POLR role. CalCCA also rejected arguments regarding the need for broad jurisdictional CPUC authority of a designated POLR.
• April 28, 2025 - The CPUC approved PG&E’s AL 7326-E and 7326-E-A, allowing PG&E to update the FSR methodology. The decision implemented by this AL also now requires CCAs to post the greatest value out of the minimum requirement of $147,000, the per-customer administrative fee (# accounts*$4.24 for PG&E), or the FSR calculation. CCAs will have 60 days after the IOU POLR informs us of our new FSR calculation to complete our first FSR posting. After that, it will return to the normal deadlines of January 1 and July 1.

Changes to the FSR methodology include:
o Use the CPUC’s RA MPB to value RA, instead of the current RA Report by ED o Use the IOU POLR’s system average residential and nonresidential customer generation rates, instead of the system average rates
o Account for CCA customers’ allocation of RA from the IOU POLR’s cost allocation mechanism (CAM), central procurement entity (CPE) allocations, and demand response (DR) resources o Remove revenues from PCIA rates of CCA customers from the IOU POLR’s generation revenues
o Incorporate seasonal generation rates
o Remove the netting of negative procurement costs against the incremental administrative costs
• May 12, 2025 - PG&E sent Pioneer our FSR calculation worksheet and advice letter. The materials indicate Pioneer must post the new FSR minimum of the per-customer admin fee. Pioneer has posted our balance to reflect our new FSR minimum.
• May 28, 2025 - An ALJ issued a ruling proposing a procedural pathway for Phase 2. Due to a lack of interest from non-IOU entities in assuming the POLR role, as indicated in the Phase 2 opening comments, the ALJ ruling proposes that the CPUC issue a decision providing a framework for its regulatory authority over a non-IOU POLR and the services it provides. That decision would then close the current proceeding and direct any non-IOU entity seeking POLR status to file a Petition for Rulemaking at least 12 months before filing an application to assume POLR responsibilities. The Commission would then resume consideration of the threshold questions and topic areas outlined in the Scoping Memo. The ALJ ruling also seeks comments on proposed definitions regarding “POLR services”, to inform the framework around CPUC regulatory authority over a non-IOU POLR entity.
• June 13, 2025 - CalCCA filed opening comments on the ALJ ruling, supporting the proposed procedural pathway for Phase 2. As for the proposed definitions regarding “POLR services”, CalCCA clarifies that the Commission needs only to adopt a definition for “POLR-specific services”, because defining “Full-severable services” or “Non-severable services” is unnecessary, as they are not within the Commission’s jurisdiction according to existing regulation and statute. CalCCA emphasizes that any POLR framework must preserve the protected autonomy of non-IOU LSEs by limiting the CPUC’s jurisdiction to POLR-specific services. • June 20, 2025 - CalCCA filed reply comments on the ALJ ruling, responding to opening comments from parties including Cal Advocates, PG&E, SDG&E, and SCE, which try to assert broader CPUC jurisdiction over non-IOU LSE POLRs unreasonably.

Utility De-energization, PSPS, and EPSS:
• July 12, 2022 -Pioneer, along with Joint CCAs, Joint Local Governments, and Rural County Representatives of California (RCRC), filed a motion with the CPUC on July 12, 2022, to consider EPSS issues in the De-energization or its own Proceeding. The arguments in the motion seek to treat EPSS events with the same regulations and oversight as Public Safety Power Shutoff (PSPS) events. • September 21, 2023- The CPUC approved a PSPS citation program for violations of the established PSPS guidelines.
• August 30-31, 2023 - PG&E provided a post PSPS report. A total of 3,928 customers were deenergized. • October 10, 2023- The Joint CCAs, RCRC, and Joint Local Governments had a meeting with the Public Advocates Office to see if there is agreement on the need to further do more with regard to Fast Trips. The Agenda Date: 11/20/2025

Public Advocates Office indicated that the CPUC and Office of Energy Infrastructure Safety are not inclined to act to regulate Fast Trips and that more data is needed. The Public Advocates Office is looking to submit a report at the beginning of 2024.
• January 16, 2024 - The data for December’s Fast Trips and YTD data came out. These are the following circuits in Pioneer’s territory with 8 or more outages in 2023:
o Placerville 2106 (EDC)- 19
o Apple Hill 2102 (EDC)- 18
o Shingle Springs 2109 (EDC)- 11
o Mountain Quarries 2101 (EDC)- 11
o El Dorado PH 2101 (EDC)- 11
o Clarksville 2104 (EDC)- 9
o Apple Hill 2104 (EDC)- 9
o Lincoln 1101 (Placer)- 8
o Penryn 1103 (Placer)- 8
o Penryn 1107 (Placer)- 8
o Brunswick 1105 (Nevada)- 17
o Brunswick 1106 (Nevada)- 15
• January 29, 2024 - A data request was made by joint CCAs (including Pioneer) using the circuits listed above to PG&E, requesting the number of customers served by each circuit, the number of life support customers, the number of medical baseline customers, and the number of critical facilities served by each circuit.
• March 8, 2024 - Part of the information we were seeking regarding the data request has been returned.

Pioneer staff will be reviewing this information.
• August 23, 2024 - PG&E completed our data request made in January, except for information regarding hardening projects on the circuit, including their pole numbers, project location, and timeline, and the type of hardening work to be completed. On the grounds that these questions are out of scope and are unduly burdensome. Pioneer staff will review the remaining data request provided. • May 8, 2025 – The CPUC will host a workshop regarding outage data collection, specifically focusing on data definitions and reporting.
• August 22, 2025 - Commissioner Baker and the Administrative Law Judge issued a ruling revising the scoping memo and schedule for Track 1 (outage reporting) of the safety and reliability proceeding. As it currently stands, the parties have submitted comments on the utilities’ current outage reporting and changes they would like to see, and the CPUC held a workshop during which our coalition presented our recommendations. The original plan for CPUC staff to issue a staff proposal for a revised set of reporting requirements, which would then be the subject of another workshop and opening/reply comments. The new plan is for the large utilities to submit a joint draft of the customer reliability report template by October 31.

Afterward, parties can file opening and reply comments on the proposal by November 14 and December 3, respectively.

CEC Load Management Standards (LMS):
• October 12, 2022 - The CEC adopted the Load Management Standards regulation which requires the development of a statewide standard tool for authorized rate data access by third parties that is compatible with each IOU, large POUs, and large CCAs with the idea that electricity customers or their authorized third-party agents can look at rates that the customer is eligible to switch and allow the customer to change the customer’s current rate to rates they qualify for.
• June 8, 2023 - CEC staff provided a schedule of the key LMS adoption and compliance dates. • August 1, 2023 - Pioneer, through Calpine, uploaded its rates and will continue to work with Calpine on uploading all time-dependent rates to meet deadlines.
• January 17, 2024 - Workshop on the implementation of LMS. Comments on the workshop are due on January 31.
• March 21, 2024 - Pioneer’s LMS plan presented to the Pioneer’s Board for approval. • March 26, 2024 - Pioneer submitted the Board-approved LMS plan.

Agenda Date: 11/20/2025

• April 1, 2024- All large CCAs are required to file their plan for compliance with LMS regulations. • April 16, 2024- CEC held a scoping meeting to discuss the development of the statewide rate access tool.

Discussions on how the tool will be funded are ongoing. • May 31, 2024- CPUC granted PG&E’s request to delay commencement of enrollment in its dynamic rates pilots from June 1, 2024, to November 1, 2024.
• July 15, 2024 - The CEC requires LSEs to jointly develop and submit a Single Statewide Tool (SST) for review by October 1, 2024. The joint IOUs, led by SDG&E, released a 50-page draft of a proposed model for the SST and will host weekly workshops to receive input from CCAs and POUs. • September 4, 2024 - Pioneer met with CEC staff to receive feedback on our LMS Compliance Plan and discuss the development of our LMS programs.
• October 1, 2024 - In compliance with LMS regulation requirements, Pioneer filed the Single Statewide Tool concept design, terms and conditions, and pleading document, jointly with the IOUs, Large CCAs, and POUs.

In addition, Pioneer submitted our individual LMS Load Flexibility Programs List to the CEC. • January 17, 2025 - CalCCA filed comments on the LMS docket, urging the CEC to pause its LMS implementation and assess next steps regarding the necessity for LMS requirements and funding for the SST development.
• February 21, 2025 - A small group of CalCCA Directors met with CEC Commissioner McCallister to discuss issues with the current application of LMS regulations by CEC staff, including how inconsistently the regulations are being applied among different CCAs and the steering of specific outcomes versus a non-biased review process based on economic and technological feasibility. Commissioner McCallister stated his intentions to work with his LMS staff to expedite CCAs’ LMS Compliance plans for approvals through increased flexibility.
• March 5, 2025 - Pioneer corresponded with CEC LMS staff regarding program development in our LMS Compliance Plan. We provided an update that our LMS programs are not currently set up to connect price signals to the CEC’s MIDAS system, which is currently not functioning well, per an operations update from our vendor, who handles MIDAS interactions, Calpine. Pioneer will continue to monitor the situation to determine if it is technologically and financially feasible to integrate this component of MIDAS price signals into our LMS programs in the future, once the MIDAS system issues are resolved. • May 8, 2025 - The CEC will vote in a business meeting to delay the SST submission until May 8, 2026. • June 19, 2025 - The CEC issued a formal revision request letter to Pioneer regarding our LMS Compliance Plan, which we are directed to revise to, in part, commit to offering the hourly flexible rate pilot programs of PG&E. The CEC directs us to file our board-approved revised plans by September 17, 2025, or 1 week following board approval of the revised plan.
• September 19, 2025- Following Board approval at the September Board meeting, Pioneer submitted its revised LMS Compliance Plan, with the language additions requested by the CEC, to the CEC LMS docket.

Power Charge Indifference Adjustment (PCIA):
• February 20, 2025 - The CPUC issued a new rulemaking to update and reform ERRA and PCIA policies and processes. This rulemaking was created as an avenue to address the RA MPB issue in the previous PG&E ERRA 2025 Forecast, where PG&E argued that a new RA MPB methodology is needed to reduce the price.

Track 1 of the proceeding will consider changes to the RA MPB calculation on an expedited basis, aiming to implement the updated methodology in the upcoming October release of the annual MPBs. Track 2 of the proceeding will consider broader issues, including a review of revisions to the MPBs, evaluation of the need for ERRA-specific implementation guidance for RA program changes, such as SOD, strategies to reduce rate volatility, additional guidance for vintaging resources, and assessment of the need for modifications to bundled procurement plan processes. All CCAs are named as individual respondents, but all CCAs will file our responses collectively under CalCCA.
• March 18, 2025 - CalCCA filed opening comments on the PCIA OIR, arguing that the CPUC has an obligation to both bundled and unbundled customers to administer the PCIA framework fairly and accurately, ensuring impartiality. CalCCA included arguments that caution the CPUC against making changes to the PCIA framework or MPB methodology that would only serve to benefit bundled customers in current market Agenda Date: 11/20/2025

conditions, which is considered a cost-shifting, not an affordability measure. CalCCA also commented on the five RA MPB revision proposals set forth by ED, advocating for the CPUC to (1) reject including historic RA transactions in the RA MPB, (2) utilize a single RA MPB incorporating system, flex, and local values, (3) exclude affiliate transactions from the RA MPB, (4) exclude swap and sleeve transactions from the RA MPB, and (5) utilize monthly values for the RA MPB, instead of the current annual one, to reflect seasonality more accurately. Opening comments by the Joint IOUs argued for the inclusion of revisions to the RPS MPB in Track 1, as well as requesting that the CPUC consider the issue of their portfolio management and negative PCIA rates.
• April 2, 2025 - CalCCA filed reply comments on the PCIA OIR, reasserting the CCAs’ positions on the RA MPB revision proposals, and arguing that the Joint IOUs’ proposals to incorporate RPS MPB revisions and portfolio management concerns are not within the scope of Track 1, and the issue of negative PCIA rates should not be reopened altogether.
• April 8, 2025 - The Scoping Ruling for Track 1 was issued, setting a narrow focus on revisions to the RA MPB methodology, including the consideration of incorporating historic RA transaction data, combining of system, local, and flex values, and eliminating transactions that are duplicative or not reflective of market-based transactions. The Joint IOUs’ proposal to consider revisions to the RPS MPB, portfolio management, and negative PCIA rates was not included in the Track 1 scope. The ruling directs all parties to address the issue of retroactive rate setting in their opening briefs, presenting arguments on whether it is appropriate to apply a revised RA MPB methodology to the 2025 ERRA true-up. The ruling aims to produce a Track 1 PD by May 2025 and a final decision by June 2025.
• April 21, 2025 - Parties submitted opening briefs. The briefs were largely legal arguments, with CalCCA arguing that the application of any changes to the RA MPB to true-up 2025 rates is not allowed under the prohibition against retroactive ratemaking, and that any decision must be supported by substantial evidence and narrowly tailored to address the supposed transaction volume problem. The IOUs also filed testimony with substantive arguments supporting their position that the CPUC should look at historic RA transactions when determining the RA MPB.
• April 23, 2025 - CalCCA filed an opposition to the IOUs' motion to admit testimony, arguing that such testimony is inconsistent with the procedures established by the Administrative Law Judge and prejudices other parties.
• April 30, 2025 - Parties filed reply to briefs primarily focusing on the legal arguments and the issue of whether to include historic RA transactions in the calculation of the RA MPB. CalCCA also filed its own testimony in response to the IOUs'. This may create a procedural and due process issue for the CPUC, which could potentially delay a decision.
• May 23, 2025 – The Administrative Law Judge issued a PD on Track One of the PCIA rulemaking. If adopted by the Commission, the PD would implement a variety of changes to the RA MPB methodology, intended to make the result of that calculation more representative of the RA value. Many of the changes were generally agreed upon by the parties, including the elimination of non-market transactions and the combination of the three different RA products (local, flex, and system) into a single RA MPB calculation. The most controversial change regarded whether to include more historical transactions and, if so, from how far back. The PD would include transactions dating back up to four years. The PD would also apply these changes to true-up currently effective 2025 rates, which will create a significant under-recovery that will need to be collected in the 2026 rates, increasing the PCIA. In comments on the PD, CalCCA will oppose both the four-year historic transaction period and the application of the revised RA MPB to 2025 rates. • June 27, 2025 – The CPUC issued a Final Decision adopting the PD on Track 1 of the PCIA rulemaking. As described above, the effect of the decision will decrease the value of the IOU’s generation resources in rates effective in 2025, which will increase the 2025 PCIA under-collection. That under-collection will need to be recovered in the 2026 PCIA rates, resulting in an increased rate for Pioneer’s customers. • July 28, 2025 – CalCCA applied for rehearing of the Track 1 Final Decision, requesting that the CPUC reconsider its decision to apply the revised RA MPB to 2025 PCIA rates. CalCCA argues that the CPUC’s Final Decision commits legal error because application of the RA MPB to 2025 PCIA rates violates the prohibition against retroactive ratemaking.
• October 31, 2025 - The CPUC issued an order on the Applications for Rehearing filed by CalCCA and jointly by Ava Community Energy Authority (Ava) and San Jose Clean Energy. The Order rejects the claims that the Agenda Date: 11/20/2025

CPUC's application of its revised RA MPBs to currently effective rates constitutes impermissible retroactive ratemaking and that its decision is unsupported by substantial evidence and contrary to statute and constitutional due process requirements.

Demand Response:
• September 18, 2025 – The CPUC instituted a rulemaking aimed at enhancing demand response in California.

The CPUC issued a Demand Response Guiding Principles Staff Report, which proposes to update demand response principles to ensure demand response is predictable, reliable, consistent, cost-effective, and supports California’s energy and environmental goals. The proceeding will address a variety of demand response and demand management topics, such as: (1) updates to demand flexible rate systems and processes; (2) dual participation in demand response programs and dynamic rates; (3) valuation methodologies and evaluation metrics for demand response; (4) CAISO market integration topics; and (5) the impact of RA SOD implementation on demand response valuation. 1 Attachment 3: Communications, Outreach & Customer Care Updates Date: 11/20/2025
NOTABLE ACHIEVEMENTS –OCTOBER 2025
• The Calpine Community Benefits Grant program awards were announced, with Feeding the Foothills, KVMR radio, and Silver Wishes each receiving grant awards ranging from $10,000 to $25,000.
• Seasonal programs ended, marking a significant increase in program participation year-over-year and overwhelmingly positive response from customers.
• Expansion efforts continue to move forward, with continued interest and enthusiasm from throughout Northern California.

WEBSITE
The conclusion of our paid media campaign resulted in a decrease in website traffic, with 5,000 fewer page views and 3,000 fewer viewers compared to September. However, website traffic was supported by a program-focused email blast that went out on October 9th (+2,500 users that day).

Despite the drop in traffic, the Residential Programs page had its best month by far, likely due to the newsletter. Top five pages:

1. GridGen

2. Home

3. PowerShift Rewards

4. AC Tune-Up

5. Residential Programs

PIONEER IN THE COMMUNITY
Events and sponsorships, public presentations, and program support were added to Pioneer’s schedule of regular outreach events, with a presence at more than two dozen community events, including:

Community Outreach & Sponsorships
• Rocklin Chamber GRC Meeting
• El Dorado County Chamber of Commerce Lunch Presentation • City of Rocklin Business Walk
• Rocklin Chamber Breakfast
• Auburn Senior Fair
• Auburn Field Day
• City of Lincoln State of the City event
• Fruit Shed Festival, Loomis
• Pioneer Volunteer Opportunity- Feeding the Foothills
• El Dorado CSD Trunk or Treat event
Programs support
• Clean Fleet Revenue Program meeting with Placer County • Clean Fleet Revenue Program meeting with Placerville
• Meeting with FuSE staff
• Ice Energy Meetings
• Community Advisory Committee Meeting

Expansion
• Colusa County Board of Supervisors meeting
• Mail and email 30 day notice to existing members, associate members, and proposed members
• Meeting with Williams City Manager
• Meeting with Colusa County Assistant CAO
• Meeting with Placerville City Council – Expansion
• Meeting with Madera County CAO, Chowchilla City Manager – IAS Findings • Updates with City of Colusa City Manager
• Check in with City of Williams Interim City Manager
• Expansion Ad Hoc Committee Meeting
Field Days were held to connect directly with customers at the Auburn Senior Center and in Shingle Springs.

CUSTOMER CARE
Chatbot
There was an overall decrease in chatbot activity during the month of October. Similar to website traffic, the busiest day was October, coinciding with the release of the newsletter. Monthly totals:
• 458 interactions
• 124 live conversations, with an average duration of 23 minutes, 27 seconds. • The average customer satisfaction rating is 5 out of 5.

The call center fielded 450 total calls (down 28% from September). Billing Inquiry was the most frequent topic, at 15%, and NEM was the second most frequent, at 13%. A total of 89 surveys were completed with a 93.3% satisfaction rate.

SOCIAL MEDIA
The Community Benefit Grant check presentation post had the greatest engagement on both Facebook and LinkedIn. Feeding the Foothills reposted and they got 27 reactions and 3 shares.

Silver Wishes also posted a thank-you note that received 19 reactions and 3 comments. Our Halloween posts performed best on Instagram.

Attachment 4: Program Updates
Date: 11/20/2025
AC Tune-Up Rebate
• Program season ended October 1, and applications were accepted through October 15 • 2,066 program participants in 2025 season.
• 227 contractors participating in program to date
• Customer feedback has been overwhelming positive and cited in many 4-star Google reviews GridGen
• Pioneer has generated a total of 276 leads. However, not all leads follow through on system installation
o 109 customers in the active pipeline
o 26 projects completed and received final inspection
o 21 customers completed and achieved permission to operate • 258.57 KW of solar capacity installed
• 103,161.53 kWh of clean energy generated
• Customer testimonials are being collected to support marketing efforts PowerShift Rewards
• Season ended October 31, though enrollment is available year round • 2,248 enrolled customers
• 4.0 MWh energy reduction; 1.3 mW load shed
• Program partner (Uplight) is calculating incentive amounts • Pioneer to send customers advance notice of incentive payments. Incentives likely issued by December 15
Ice Energy Storage
• More than 200 site visits have been conducted
o Site surveys have taken place at 33 locations
o Potentiel for 182 Ice Bears across all sites
• Participation agreements under review
o 198 Ice Bears would be installed
• Discussions with the City of Rocklin continue, with a focus on five (5) specific facilities.

Clean Fleet Revenue
• Program is active with outreach to all existing member agencies • Signed MOU’s from the City of Rocklin and City of Nevada City have been received. The City of Auburn has added the item to the agenda for approval.
• Staff will be meeting with the City of Lincoln and Placer County Transportation Planning Agency to discuss future solar and EV charger projects.

Agenda Date: 11/20/2025

LED Discount (discounted LEDs at local retail locations) • Participants include 21 independent retailers and seven Dollar Tree stores, bringing the total number of participating stores to 28
• This program continues to remain popular with retailers providing positive feedback and continuing to provide Pioneer marketing and visibility through community partnerships Community Advisory Committee
• The Community Advisory Committee (CAC) met on October 29, 2025. The agenda included an update on the Incentive Finder program; discussions about ideas for 2026 programs and renewable energy in California
Hourly Flex Pricing Pilot (credits for energy conservation for Ag customers) • Two customers enrolled in the program (19 meters/accounts) • The program is administered by PG&E
• The application period remains open
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Pioneer Community Energy
Glossary of Terms
CAISO - California Independent System Operator - a non-profit independent system operator that oversees the operation of the California bulk electric power system, transmission lines and electricity market generated and transmitted by its members (~80% of California's electric flow). Its stated mission is to "operate the grid reliably and efficiently, provide fair and open transmission access, promote environmental stewardship and facilitate
effective markets and promote infrastructure development. CAISO is regulated by FERC and governed by a five-member governing board appointed by the governor.

CALCCA - California Community Choice Association -Association made up of Community Choice Aggregation {CCA) groups which represents the interests of California's community choice electricity providers.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

See Demand.

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

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

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

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

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

PCCl - RPS Portfolio Content Category 1- Bundled renewables where the energy and REC are dynamically scheduled into a California Balancing Authority (CBA) such as the CAISO. Also known as "in-state" renewables.

PCC2 - RPS Portfolio Content Category 2 - Bundled renewables where the energy and REC are from out-of-state and not dynamically scheduled to a CBA.

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

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

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

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

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

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

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

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

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

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

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

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

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

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