Pioneer Community Energy Board of Directors
March 20, 2025

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 3/20/2025

PERSONNEL
We are excited to introduce two new members to the team.

1. Terrance Rodgers joined March 3rd as the Project Development Manager. Prior to joining Pioneer, Terrance worked at RCRC since 2015 and serve as the Economic Development Officer, and the Director of Forest Resiliency and Manager of Project Development for Golden State Natural Resources. Terrance was responsible for identifying and establishing opportunities for economic growth, facilitating community and economic development planning initiatives, identifying, and securing funding sources for county and regional infrastructure projects, and liaising with local organizations, businesses, and individuals in RCRC communities and regions. Terrance holds a Bachelor of Arts Degree in Government from the California State University of Sacramento.

2. After graduating from the University of Hawaii School of Law in 2013 and passing the California bar exam in 2014, Kris has worked as in-house counsel for several companies in a regulatory compliance, transactional, and contract management role. He has extensive experience working with government agencies and third-party vendors in managing the buildout of state-of-the-art facilities including, but not limited to, securing permits and licenses, reviewing contracts, and ensuring timely completion of projects.

On weekends, Kris likes to golf, play basketball, and go hiking with his dog.

There is one active recruitment for the Senior Financial Analyst position.

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) The following agreements have been carried out by the Chief Executive Officer, consistent with the authority delegated by the Board:
 Granicus Master Subscription Agreement for meeting video software in the amount of $17,029.46  Capital Network Solutions Consultant Services Agreement Amendment No. 1 for a total agreement amount not to exceed $75,000
 Amperon Change Order to contract extending trial period to May 20, 2025, with no additional cost.

BIOMASS TOUR
Pioneer hosted a Legislator Biomass Education Tour at Sierra Pacific Industries (SPI) in Lincoln, CA on March 7, 2025, in collaboration with California Biomass Energy Alliance, Calforests, and Placer County Air Pollution Control District. Legislators and staff members from the offices of Senator Niello and Cabaldon and Assemblymembers Calderon and Hadwick were in attendance as well as Director Ivy. Attendees were able to tour the SPI facilities, see how biomass waste is processed into bioenergy, and participate in a lively presentation and discussion around the myths, facts, and benefits of biomass energy.

Plf)NEER

COMMUNITY ENERGY
Agenda Item: IV-B Agenda Date: 3/20/2025

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (“CAISO”) TOUR
We currently have four (4) Board Members, including Alternates, attending the CAISO tour on April 9th. Please reach out to Teresa if you are interested. Further details below:

TIME: 12:45 - Arrive and security check in
1:00 - 3:00 Tour and discussion
ADDRESS: 250 Outcropping Way, Folsom, CA 95630
The tour will begin at 1:00 p.m. and last approximately 90 minutes.

Due to security protocols, Pioneer must file a final guest list by March 26. Additional information and the required waiver will be sent to you electronically if you decide to attend.

IMPLEMENTATION PLAN AND STATEMENT OF INTENT
Staff submitted Addendum No. 3 to Pioneer’s Implementation Plan and Statement of Intent on March 11th. The California Public Utilities Commission has ninety (90) days to approve or deny the plan.

Staff has informed all the potential new members of the filing and have received very favorable responses.

GOVERNANCE COMMITTEE
The Governance Committee was formed by the Board in December 2024. Its purpose is to discuss issues related to the Pioneer’s Joint Powers Agreement and other important issues. The Committee is comprised of the Board Chair, Vice Chair, and the Chair of each of Pioneer’s Committee’s. We anticipate completing the process of selecting Chairs for our committees by end of March and launch our inaugural Governance Committee meeting in April. There are several issues for this committee including the admittance of the potential new members to the Board.

A NOTE FROM JOHN HIDAHL’S FAMILY
For Board Directors new to the Board in 2025, John Hidahl was our Board Director from El Dorado County and instrumental in the expansion of Pioneer into the county. He passed suddenly late last year.

Staff attended his Celebration of Life Memorial, and I wanted to share this wonderful note from his family acknowledging the important Pioneer’s mission was to John. His contributions to Pioneer will endure.

Agenda Item: IV-B Agenda Date: 3/20/2025

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

Presentations and Relevant Meetings attended by the Chief Executive Officer

1. Participated in CalCCA Weekly/Monthly Board meetings.

2. Co-Presented with the CEO of 3CE, a CCA located in Monterey, on the State of the CCAs to CalCCA’s various partners.

3. Participated in a discussion with Supervisor Yoder of Glenn County.

4. Participated in the Biomass Tour.

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report
Counterparty Name
Execution
Date Type Product Start Date End Date Notional Value
Dynasty Power Inc. 2/3/2025 Buy Renewables - PCC2 1/24/2025 12/31/2027 $ 15,360,000 Balsam Project, LLC 2/20/2025 Buy Resource Adequacy - Flex 8/1/2028 7/31/2048 $ 138,000,000 #,£},;;,,gCJtte,,r,ty,j
John Walter Hidahl OCTOBER 10. 1951 - NOVEMBER 2, 2024
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Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 03-17-2025

BOARD OF

DIRECTORS
MARCH 20, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: March 17)
APRIL 17, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: April 11)
MAY 15, 2025

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

IN THE FUTURE
Special Meeting
[time]
CAISO Tour (Board) - WED, APRIL 9
Regular Meeting
3:00 PM
CalCCA presentation (Vaughn)
General Function I
Consent 1a Minutes for Approval-FEB 27, 2025 Minutes for Approval-MAR 20, 2025 Minutes for Approval-APR 17, 2025 Contracts for renewal per Purchasing Policy (Koehn)
1b Receive Draft Financials: JAN 2025
(Koehn)
Receive Draft Financials: FEB 2025
(Koehn)
Receive Draft Financials: MAR 2025
(Koehn)
Amendment to Uncollectible Accounts
Policy (Koehn)
1c RES establishing the EPRC as an ad hoc
Advisory Committee to CEO (GC)
AMI audit (Koehn) EE Health & Benefit ad hoc Committee
(Koehn)
1d RES amending Resolution 2021-1
executing Long-term PPAs not
exceeding 1.5% of Pioneer’s annual
procurement budget as a maximum
annual notional amount, together with
a maximum 20-year term
(Kang/Ruderman)
Regular 2 ICE Energy
(discussion- Stassi-Vanacore) guest
Legislative Platform
(discussion-Kang) guest- lobbyist
Proposed Budget (discussion-Koehn) RES Revised NEM Policy (action-Koehn)
3 RES Toolkit program
(action- Stassi-Vanacore)
RES LCFS program contract
(action- Stassi-Vanacore)
4 RES Brillion Program and program
updates (action- Stassi-Vanacore)
RES EV Charging Station Grant
(action- Stassi-Vanacore)
5 RES Amendment to RES 2023-33 Feed-in Tariff (FiT) re: adding programs (i.e., solar + storage) (action-Kang)
6 State of the Utility
(discussion-Eckert)
General Function II Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs; personnel
introductions (Terrance, Kris);
Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs; personnel
introduction (Lee);
QTRLY Updates: Strategic Plan
Objectives; Sponsorship Activity
Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs;
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
Board Workshop (discussion-Eckert)
Informational Items
Glossary of Terms
I
17 I I
I I
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 03-17-2025
AUDIT/FINANCE COMMITTEE TO BE SCHEDULED – MARCH
in-person & remote locations
TO BE SCHEDULED – EARLY MAY
in-person & remote locations
Greg Janda, Chair
Richard Pearl
Gary Petersen
David Ring
o Selection of Officers o Budget
o Facilities

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE
MARCH 12, 2025 – 11:30 AM
zoom only IN THE FUTURE
Gary Petersen, Chair
Alice Dowdin Calvillo, Vice Chair
Ryan Carter
Greg Janda
Sean Lomen
 Selection of Officers
 Review of EPRC Authority in Approval of Long-Term PPAs  Approve long-term PPAs

EXPANSION

AD HOC COMMITTEE
MARCH 19, 2025 – 3:00 PM
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy
Suzanne Jones
Lori Parlin
o Selection of Officers
o Discuss next phase of Expansion
GOVERNANCE COMMITTEE TO BE SCHEDULED – EARLY APRIL
in-person & remote locations IN THE FUTURE
Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o Selection of Officers
o Timing of installing Board Members for the Expansion
Territories
o Introduction of the Compensation Study

COMMUNITY ADVISORY COMMITTEE

TO THE CHIEF EXECUTIVE OFFICER
APRIL 23, 2025 IN THE FUTURE
Meets on the 4th Wednesday
(even-numbered months)

Attachment 2: Legislative and Regulatory Update
Date: 3/20/2025
Legislative Affairs
• In preparation for the 2025 Legislative Session, Pioneer is engaging in early talks within the Legislature, whose primary objective this year is to address the energy affordability crisis as outlined in Governor Newsom’s Executive Order N-5-24. Pioneer will advocate for biomass development by educating legislators on its potential to be an integral tool in facilitating cost effective wildfire mitigation, which has been the main contributor in the sharp rise of utility bills over the last few years.

Pioneer aims to support a legislative proposal that will provide funding for biomass development, through existing sources of funding.
• On March 1, 2025, Governor Newsom proclaimed a state of emergency regarding the state’s overgrown forests and its associated wildfire risks. The proclamation will cut bureaucratic red tape including suspending CEQA and the Coastal Act, among other measures, to expedite critical forest management and fuel reduction projects.
• Pioneer carried out a Lobby Day on February 26, 2025 to meet with current and future constituent legislators including Assemblymembers Tangipa, Hadwick, Gallagher, and Patterson and Senators Cabaldon, Niello, Alvarado-Gil, and Dahle. Pioneer used this opportunity to educate new legislators on our organization’s missions and goals, focused on affordable rates and biomass development. In meetings with existing delegation members, Pioneer provided updates on our rate savings and discussed possible collaboration efforts on biomass policy initiatives as the legislative session progresses.
• Pioneer hosted a Legislator Biomass Education Tour at Sierra Pacific Industries (SPI) in Lincoln, CA on March 7, 2025, in collaboration with California Biomass Energy Alliance, Calforests, and Placer County Air Pollution Control District. Legislators and staff members from the offices of Senator Niello and Cabaldon and Assemblymembers Calderon and Hadwick were in attendance. Attendees were able to tour the SPI facilities, see how biomass waste is processed into bioenergy, and participate in a lively presentation and discussion around the myths, facts, and benefits of biomass energy.

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
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
[Publish Date] Agenda Date: 3/20/2025

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
R.22-07-005 OIR to Advance Demand Flexibility
Through Electric Rates
Limit negative impacts of the
Income Based Graduated Fixed
Charge and educate Pioneer Board
and customers prior to the rollout.

A.20-02-009; A.21-03-008;
A.21-06-001; A.22-05-029;
A.24-05-009
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
Reduce the ERRA impact on the
PCIA; increase data transparency
from the IOUs
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
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 of 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.

Attachment 2
[Publish Date] Agenda Date: 3/20/2025

• January 29, 2024- 60 days from the Decision- CCAs finalized two provisions with Accion for website work and third-party administrator. In addition, CCAs submitted a revised tariff, a program participation request, power purchase agreement, rate schedule, and 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- There is an agreement 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- There was a meeting with CPUC staff on implementation of AB 843. Brad Hill will be moving over to Natural Resources Agency.
• March 28, 2024- Assembly Member Aguiar-Curry submitted a letter of support to the CPUC for the 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 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 day of the effective date of the decision. Work has been delayed pending final agreement from all parties to revisions to the third-party administrator 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 scheduled. • Pioneer has completed the implementation of the BioMAT program. The website and all necessary documents for BioMAT are live.
• June 20, 2024- CPUC issued a Draft Resolution to approve participating CCAs’ forecast revenue requirements, which is $0 for 2024-2025 for all participating CCAs, since no BioMAT projects are forecasted to COD before then.
• September 1, 2024- CPUC granted the joint CCAs’ extension request for the BioMAT application for prudent contract management, since there are no BioMAT contracts to report on. 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 forecasted revenue requirements for 2026 is suspended for review for up to 120 days beginning March 3, 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 Attachment 2
[Publish Date] Agenda Date: 3/20/2025

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 will be reviewed by the CPUC.

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 qualify 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 growth of biomass 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 the growth of biomass. • 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 to deny the petition due to the clear 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 26, 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 originally proposed base case and sensitivity portfolios.

Renewables Portfolio Standards:
• September 12, 2002- The California Legislature adopted SB 1078 which established the renewables portfolio standards (RPS) program 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. 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 the certification of electrical generation facilities as eligible renewable energy resources and adopting regulations for the enforcement of RPS procurement 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.

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.

Attachment 2
[Publish Date] Agenda Date: 3/20/2025

• June 14, 2023- CalCCA filed comments recommending the CPUC fully 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 needlessly discriminate against CCAs to prevent their growth; 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 next 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. CPUC is seeking to consolidate since 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 from CCA expansion in the event of noncompliance and add the ability for the CPUC to waive penalties if CCAs can show reasonable efforts to comply 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 that would waive financial penalties as well under certain circumstances. A slice of day waiver would also be available. • February 23, 2024- There was a SOD proposal workshop. CalCCA is asking for a delay in SOD implementation from 2025 until 2026 because the showing and compliance tools are not working properly. • March 22, 2024- CalCCA submitted comments on the RA Program with regards to considering RA reforms and refinements and establishing forward RA procurement obligations. CalCCA believes the focus should be to adopt 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 included a host of other issues including the CPUC’s insistence on using a higher than necessary planning reserve margin (PRM), 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 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 Attachment 2
[Publish Date] Agenda Date: 3/20/2025

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- Energy Division (ED) published the revised version of their 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 originally 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 their 2024 CPE Annual Compliance report. The report shows they are short in their centralized procurement of RA for 3 years forward. • October 29, 2024- The CPUC issued a PD for RA Track 2, which deals with the PRM and CPE framework.

Regarding the proposed PRM, the Commission agreed additional vetting and further analysis is needed, authorizing ED to undertake a further revision of the 2026 PRM analysis which will be considered in Track 3 of the proceeding. As for the CPE framework, the Commission successfully adopted CalCCA’s proposal to lock in CPE allocations one year earlier, giving LSEs 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 adverse effects of 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, but with an option for LSEs to apply for temporary System Waivers in peak months (June to September) for requirements above a 17% PRM based on a cost threshold.
• January 17, 2025- CalCCA filed their 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 through 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 21% PRM for peak months, paired with an option for LSEs to apply for temporary System Waivers in peak months for requirements above 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 Attachment 2
[Publish Date] Agenda Date: 3/20/2025

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 the price mitigation Proposal B which would allow for System RA waivers, and instead recommended the adoption of a PRM that will allow the grid to consistently meet the pre-determined target of 0.1 LOLE.

Demand Flexibility:
• June 30, 2022- AB 205 passed giving the CPUC the authority to approve a pricing structure that incorporates an Income Based Graduated Fixed Electricity Charge (IGFC). • July 14, 2022- The Commission issued an OIR to begin this proceeding to establish demand flexibility policies and modify electric rates to advance the following objectives: 1) enhance the reliability of California’s electric system; 2) make electric bills more affordable and equitable; 3) reduce the curtailment of renewable energy and greenhouse gas emissions associated with meeting the state’s future system load; 4) enable widespread electrification of buildings and transportation to meet the state’s climate goals; 5) reduce long-term system costs through more efficient pricing of electricity; and 6) to enable participation in demand flexibility by both bundled and unbundled customers. • July 31, 2023- Parties submitted Comments on the IGFC Implementation Pathways considering the ALJ Ruling’s questions.
• August 21, 2023- CalCCA submitted Reply Comments to refute parties’ arguments regarding including the PCIA or Competitive Transition Charge (CTC) as fixed costs eligible for inclusion in the IGFC. • October 27, 2023- 22 Democratic lawmakers sent a letter to the CPUC asking for an extension of the timeline for the proceeding and require public participation hearings before implementing an IGFC. • November 3, 2023- Track A (IGFC)- CalCCA filed a reply brief continuing to refute party proposals that the PCIA be included in the IGFC and noting that the parties advocating for inclusion of the PCIA have not addressed the arguments put forth by CalCCA.
• December 15, 2023- Track B (demand flexibility)- The CPUC issued a PD which directs PG&E to expand the Valley Clean Energy Ag-Fit pilot program. CCAs that participate in the expanded pilot may receive $20/kW for each year of customer enrollment in the PGE Ag-Fit pilot as an incentive. The incentive is capped at $1.8 million for PG&E’s territory. The budgets are for all the CCAs wanting to participate to share. PG&E will be administering the pilot so there will be no administrative costs, but several of the CCAs want to have a say in how the pilot is administered and the education and outreach of the pilot. December 18, 2023- Track A (IGFC)- CPUC issued a ruling requesting implementation information from the IOUs on the IGFC. The ruling directs the IOUs to file additional information about the proposed budgets for implementing the first income-graduated fixed charges by January 24, 2024. • January 23, 2024- (Track B) There was a revised PD on the expanded pilots. Pioneer is considering offering the expanded Ag-Fit program to its customers. The pilot will be administered by PG&E so it will involve minimal work on behalf of Pioneer staff, but it will also bolster our Load Management Standards program and keep us competitive with PG&E.
• January 26, 2024- The CPUC approved the expanded pilots revised decision. In D.24-01-032 to Advance Demand Flexibility Through Electric Rates, the CPUC directed PG&E to expand the Valley Clean Energy Ag Real Time Pricing Pilot (VCE AgFIT Pilot). The decision orders PG&E to extend the duration and expand participation of the VCE AgFIT Pilot to agricultural customers throughout PG&E’s service territory. • January 30, 2024- (Track A)- There was a press conference held by a group of 20 Democratic Legislators calling for the repeal of income-graduated fixed charge. AB 1999 would repeal the income-graduated fixed charge approved under AB 205 (2022) and replace it with a $5 fixed charge for CARE customers and a $10 fixed charge for all other residential customers.
• February 13, 2024- Pioneer staff sent PG&E an email indicating interest in possibly participating in the expanded pilot expansion program, particularly the Ag Pilot. • February 13, 2024- at the Senate Utilities, Energy and Communications hearing the IGFC was brought up by CPUC president, Alice Reynolds, who indicated the CPUC was working on an IGFC decision possibly by the end of Q1.

Attachment 2
[Publish Date] Agenda Date: 3/20/2025

• March 1, 2024- There is an expanded pilot workshop to address dual participation, since some demand flexibility programs are dual enrollment prohibited. Dual Participation is allowed for- Critical Peak Pricing:
(Peak Day Pricing and SmartRate), Electrification Rates: (E-ELEC), TOU Rates (E-TOU, E-TOU-D), Simple NEM and NBT, and ELRP Subgroup A: (A1-A6). Dual Participation is Prohibited- Supply-Side DR Programs (BIP, CBP, ART, DRAM, non-DRAM DR RA Contracts, DSGS Option 2), Flex Market Pilot, DAHRTP, ELRP Subgroup B: B1-B2, and Other Event-Based Load-Modifying Programs (OBMC, SLRP). • March 25, 2024- PG&E submitted their Tier 2 AL for implementation plans for PG&E’s Expanded Ag Pilot. 5 CCAs have expressed an interest in participating in PG&E’s Ag Pilot in 2024 (Ava, SVCE, VCE, 3CE, and Pioneer). PG&E will launch the pilot in June of 2024. Participants will continue to pay their current bill and will receive the shadow bill, which they will not pay. The shadow bill will illustrate a customer’s potential savings under the dynamic pilot rate. There is also a $20 per unbundled kW per year incentive, subject to a $1.8 million cap for all CCA incentives.
• March 27, 2024- The CPUC issued a proposed decision addressing AB 205 (Income Graduated Fixed Charge) requirements for electric utilities. The earliest this proposed decision could be adopted is May 9, 2024. This decision authorizes all IOUs to shift the recovery of a portion of fixed costs from volumetric rates to a separate, fixed amount on bills without changing the total costs that utilities may recover from customers.

As a result, this decision reduces the volumetric price of electricity (in cents per kilowatt hour) for all residential customers of IOUs. The CPUC did not adopt the IOUs’ proposal and instead the proposal would have Tier 1 (customers enrolled in CARE) pay $5 a month, Tier 2 (customers enrolled in FERA or who live in affordable housing restricted to residents with incomes at or below 80% of Area Median Income) pay $12 a month, and Tier 3 (all other customers) pay $24.15 per month. This new billing structure would apply to all residential rates of the IOUs, except for master-meter rates that are not sub-metered. • May 9, 2024- CPUC approved implementation of the Income Graduated Fixed Charge without any changes to the structure described in the previous bullet.
• June 12, 2024- CalCCA filed reply comments on the Track B Proposal, urging the CPUC to reconsider the process for updating marginal cost values and to clarify a cost recovery structure that ensures CCA customers do not get double-charged for being unbundled.

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 seeks 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 looks good with the PCIA remaining negative over many vintages, but this will 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), but 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 Proposed Decision 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 Attachment 2
[Publish Date] Agenda Date: 3/20/2025

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 17.9% increase.
• November 30, 2023- The PD for the PG&E 2024 ERRA Forecast came out. 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 methodology to the use of excess prior year RECs or a last-in-first-out methodology. The CPUC ruled with PG&E on a last-in-first-out methodology. • December 12, 2023- A revision to the proposed decision 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.
• December 29, 2023- PG&E submitted their 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. 2021 ERRA proceeding is still open but coming to an end, 2022 is still busy and 2023 is just starting up. 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 out of this proceeding altogether, possibly in hopes 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, which will result 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 against considering these broad policy questions, which fall outside the scope of the ERRA Forecast proceeding. CalCCA also argues that implementing an RA value cap would inappropriately inflate PCIA rates, shifting costs to unbundled customers, in violation of 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, re-opening 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 their 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 new discovery responses received from PG&E, once the ALJ re-opened the discovery window for CalCCA in July 2024.
• October 4, 2024- Energy Division released the 2024 Final MPBs and 2025 Forecast MPBs that are used to calculate the PCIA in PG&E’s 2025 ERRA Forecast proceeding. They have since issued corrections to the Attachment 2
[Publish Date] Agenda Date: 3/20/2025

MPBs several times.
• October 8, 2024- In the PG&E 2025 ERRA Forecast proceeding, the ALJ issued an email ruling asking for comments regarding 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 ruling asking for party comments relating to the impact of the released MPBs. PG&E stated the released RA MPBs will result in a $500 million increase to the bundled customer generate revenue requirement, while departed 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 corresponding reduction to departed load customers. For these reasons, PG&E asks the Commission to delay the procedural timeline and consider various mitigation methods such as producing additional rate-setting scenarios and establishing a tracking account to remediate 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 their Fall Update, in which they argue 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 which involve freezing the RA and/ or RPS MPBs to 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 and met with Maria Sotero from Commissioner Reynold’s office to discuss the MPB issues and better understand what strategies the CPUC wants 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 their Annual Electric True-Up to change PG&E’s electric rates on 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 that the change should be applied prospectively in 2025 and forward, 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 urges 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 it to a close. The decision adopts PG&E’s revised proposal of common costs allocation beginning with January Attachment 2
[Publish Date] Agenda Date: 3/20/2025

1, 2025 rates. PG&E’s estimated 12-month net revenue requirement for 2025 is $2.25 billion, resulting in an expected decrease of bundled residential customers’ rates by 2% and a decrease of unbundled residential customers’ rates of 4.4%.
• December 30, 2024- PG&E filed their final Annual Electric True-Up, reflecting the CPUC’s final decision, to update their 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, which most other parties were in consensus with. CalCCA also encouraged the CPUC to address any changes in the common cost allocation methodology in a separate, non-expedited rulemaking with all three IOUs as parties, in order to ensure consistency in their practices.
• February 28, 2025- PG&E filed their 2024 ERRA Compliance Application.

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, and LSE de-registration process and compliance requirements. • July 31, 2023- CalCCA's Reply Briefs were submitted and address 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, it maintains the ability to use service bonds, and it keeps confidential the information about LSEs that trigger financial monitoring.

However, the proposed decision also approved using PG&E’s Administrative Fee ($4.24) without sufficient evidence of the costs, the CPUC should clarify that November 2024 FSR Calculation would be the earliest possible calculation under the new rules, and 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, while the other IOUs’ administrative fees are significantly less (around $.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 first FSR following IOU tariffs implementing this decision.
o Requires CCAs to file the Tier 1 audited financial report to 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 joint advice letter on 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 financial reporting, if certain trigger events such as a change in credit rating occur. This document clarifies the process and procedures CCAs must follow to comply with Tier 2 financial reporting conditions.

Attachment 2
[Publish Date] Agenda Date: 3/20/2025

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 of hand (DLOH). The IOUs also insisted 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. On the issue of minimum days required to report financial trigger events, CCAs insist on keeping 60 days, as this is the minimum amount of time required to prepare accurate financial statements due to complex 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 proforma financial statement six months prior to 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 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 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 sets 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 use the methodology in place without the Phase 1 Decision modifications. Due to the hold on the ALs, all CCAs will be obliged to post the minimum FSR of $147,000 come 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 who only wants to serve commercial and industrial customers.
• 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 joint application process, but stopping short of building out the entirety of the framework due to the current lack of interest by parties in Attachment 2
[Publish Date] Agenda Date: 3/20/2025

the designated POLR role. CalCCA also rejected arguments regarding the need for broad jurisdictional CPUC authority of a designated POLR.

Utility Deenergization, 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 Deenergization 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 regards to Fast Trips. The 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 in 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 (EDH)- 19
o Apple Hill 2102 (EDH)- 18
o Shingle Springs 2109 (EDH)- 11
o Mountain Quarries 2101 (EDH)- 11
o El Dorado PH 2101 (EDH)- 11
o Clarksville 2104 (EDH)- 9
o Apple Hill 2104 (EDH)- 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 came back. 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 type of hardening work to be completed, on the grounds these questions are out of scope and are unduly burdensome. Pioneer staff will be reviewing the rest of the data request provided.

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 are eligible 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 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.

Attachment 2
[Publish Date] Agenda Date: 3/20/2025

• March 26, 2024- Pioneer submitted the Board-approved LMS plan. • 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 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 their 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 in regard to 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 inconsistent the regulations are being applied among different CCAs and the steering of certain 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 see if it is technologically and financially feasible to add this component of MIDAS price signals to our LMS programs in the future, when the MIDAS system issues are resolved.

Power Charge Indifference Adjustment (PCIA):
• February 26, 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 deal with the RA MPB issue in the previous PG&E ERRA 2025 Forecast, where PG&E argued a new RA MPB methodology is needed to bring down 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 review of revisions to the MPBs, evaluating need for ERRA-specific implementation guidance for RA program changes including SOD, how to reduce rate volatility, additional guidance for vintaging resources, and evaluating need for changes to bundled procurement plan processes. All CCAs are named as individual respondents, but all CCAs will file our responses collectively under CalCCA.

Attachment 2
1 Attachment 3 Communications and Outreach Updates
Date: 3/20/2025
NOTABLE ACHIEVEMENTS – FEBRUARY 2025:
• Pioneer staff attended meetings and secured the needed documents from all 13 expansion communities to file our Implementation Plan with the California Public Utilities Commission.
• Extensive earned media, including in opinion leader outlets, reinforced Pioneer’s savings messages and spread the word about expansion efforts. Examples of media coverage can be found on the News & Information page of the Pioneer
website.
• With a focus on customer interaction and ensuring the accuracy of information, Pioneer has launched a social
media comment moderation program. Key to this effort is refuting incorrect information. Staff have successfully corrected misinformation and changed the tone of several online conversations.
• Our customer care team continues to successfully re-enroll customers, with another nine returns to Pioneer during
February.

CUSTOMER COMMUNICATIONS/CALL CENTER
February was a quieter month for calls, with 428 total calls (down 22% from January). A total of 98 surveys were completed, leading to a 92% satisfaction rate. The most frequent to topics/reasons for calling were billing (16.42%) and NEM (15.92%).

WEBSITE
February was a short month. Website traffic was consistent, but not busy. The Home and Residential pages were visited most often, with the traffic coming primarily from organic searches.

Our chatbot continues to take pressure off the call center, with a total of 220 interactions and 31 live conversations during February. There was no satisfaction surveys completed during February, so there is no updated rating.

OUTREACH AND ENGAGEMENT
As expansion deadlines loomed, outreach efforts focused on briefings and presentations to prospective new members and securing the documents needed to file our Implementation Plan with Plf)NEER

COMMUNITY ENERGY
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the California Public Utilities Commission. In addition, Pioneer maintained a presence at community-focused events and conducted field days to meet customers in the community.

Community Events
Rocklin Chamber of Commerce GRC meeting
River City Bank Business Outlook event
Comstock’s Women in Leadership Interview
with Board Chair
Good Morning, Rocklin Chamber Breakfast
Sunrise with Rocklin Chamber
Auburn Senior Center field day
Grass Valley City Hall field day
Expansion
Butte County: 2nd reading
Nevada County: 1st & 2nd readings
Sutter County: review of study findings;
1st and 2nd readings
Glenn County: 1st and 2nd readings
Tuolumne County: 1st and 2nd readings
City of Chico: 2nd Reading
City of Live Oak: 2nd reading
City of Orland: review of study findings,
1st & 2nd readings
City of Oroville: 2nd reading
City of Willows: 1st and 2nd readings
City of Sonora: 1st and 2nd readings
City of Yuba City: 2nd reading
Town of Paradise: 2nd reading

SOCIAL MEDIA
Pioneer’s social media presence continues to expand, with the majority of our social activity coming from outside sources like news outlets, CalCCA, and Facebook groups. Our Valentine's Day and Leadership Day performed well across the board, again demonstrating that the bet-performing posts are those that humanize Pioneer. Top performing posts for February appear below.

LinkedIn Instagram Facebook
Comment moderation has made a positive difference in Pioneer’s social presence. We have corrected past comments that have incorrect information and now monitor all comments daily. By responding to negative or incorrect information via a reply from Pioneer, we have successfully changed the tone of the conversation and also brought out supporters through reactions (likes and loves) to our comments.
#,~~ Pioneer Community Energy
, , ~ 564 followers
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Community-owned and not-for-profit we are pleased be considered as a money-saving alternative to the area's investor-owned utility.

Check out the full story from CBS13 on our website at the link below.

IJ!!!!'I CCBSNEWS liilj SACRAMENTO
Pioneer Community Energy looking to expand service in
Northern California
p,oneercommun 1ty1!nergy.org
C• Jake Trumbull and 15 others 2 comments • 1 repost
Reactions
+8
Use a power strip instead of
multiple outlets!
Turning your power
strip off when the
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If you don't hove a
power strip, just
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f) Savings Tip Tuesday
We are so proud of our leadership! From our board to our staft Pioneer leadership is the reasoo we .ire able to k.eep ~ving our customers money. Thank. you to our leader-s for leading with both heart andpurpos.e, mspmngusalltoreachhighereachday.

Attachment 4: Program Updates
Date: 3/20/2025

AC Tune-Up (rebates for AC tune-up)
• The tune-up program will relaunch April 1, 2025.

GridGen (solar + storage)
• The board approved program expansion at the February 2025 meeting to include CARE customer initiative, retrofits, and commercial customers.
• 54 customers in the active pipeline
• 6 have reached permission to operate
• 15 additional customers have signed contracts
PowerShift Rewards (incentives for energy conservation) • PowerShift Rewards will relaunch on May 1, 2025.

LED Discount (discounted LEDs at local hardware stores) • The LED Discount program is expected to end by Q2 of 2025, once all funding has been depleted.

Online Marketplace (solar and/or battery storage purchasing) • Sixteen (16) leads have been generated through the Electrum Marketplace. • Pioneer is working with Electrum to address improving local contractor participation in the program to increase customer satisfaction and utilization of the marketplace in 2025.

Hourly Plex Pricing Pilot (credits for energy conservation for Ag customers) • Pioneer is preparing letters and additional marketing materials to help promote the HFP program to agriculture customers.

Ice Energy Storage (ice technology used for AC energy reduction) • The Ice Energy Storage program is an energy efficiency and load shifting program. Customers can install an Ice Bear unit to their existing AC unit to help reduce AC load during peak times. The technology works by cooling ice during off-peak energy times. Then during peak times and when additional AC is needed, the ice is used to cool the air instead of the regular coil system in the AC until. This reduces energy costs and helps customers save money by reducing their energy use during times when prices are higher.
• The Ice Energy team have started outreach to commercial customers and a larger marketing effort is expected to launch Q2 2025.

Community Advisory Committee
• The Community Advisory Committee will meet April 23, 2025.

Plf)NEER

COMMUNITY ENERGY
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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.