Pioneer Community Energy Board of Directors
February 27, 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. Participated in a tour of a carbon capture pilot being applied to a natural gas fired power plant courtesy of Calpine Corporation

3. Attended the 2025 Business Outlook Symposium for the Sacramento Region hosted by River City Bank

4. Presented at the Nevada County Board of Supervisors regarding expansion

5. Participated in a meet and greet with Director Clark in Placerville

6. Participated in Lobby Day with the Board Chair meeting several legislators that represent our territory or strategically allied with biomass efforts

7. Participated in TV interview with Director Petersen in Nevada City

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report

5. Pioneer’s Customer Generation Rate Tables ($/kWh)
a. Residential
b. Commercial & Industrial
c. Agricultural
d. Lighting

6. Strategic Plan Quarterly Progress Report
Event Date
Member
Community Vendor Special Event Amount
CY 2024 Lincoln Lincoln Potters Baseball Club, Inc. 2024 Season Partnership $ 2,000 CY 2024 Rocklin Rocklin Area Chamber of Commerce
2024 Government Relations Committee
Meeting Sponsor $ 750
CY 2024 Statewide League of California Cities 2024 Cal Cities Partner $ 5,000 8/8/2024 Statewide
Mountain Counties Water Resources
Association MCWRA/EID Regional Leaders Reception $ 250
9/18 - 9/20,
2024 Statewide
Rural County Representatives of
California 2024 RCRC Annual Meeting $ 7,500
10/4/2024 Loomis Loomis Basin Chamber of Commerce 2024 Fruit Shed Festival $ 1,500 11/21/2024 Auburn Auburn Chamber of Commerce Auburn State of the City Dinner $ 1,500 12/7/2024 Lincoln Lincoln Area Chamber of Commerce Lincoln Hometown Christmas Parade $ 500 12/15/2024 Nevada City Nevada City Chamber of Commerce Victorian Christmas $ 500 12/7/2024 Rocklin Rocklin Area Chamber of Commerce Rocklin Tree Lighting $ 300 TOTAL $ 13,550
Quarter Ended December 31, 2024
Counterparty Name
Execution
Date Type Product Start Date End Date Notional Value
Powerex Corp. 1/31/2025 Sell Pioneer Large Hydro 2/1/2025 12/31/2025 $ 1,425,000 Agenda Planning Document – Pioneer Community Energy Updated 02-21-2025

BOARD OF

DIRECTORS
FEBRUARY 27, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: February 21)
MARCH 20, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: March 14)
APRIL 17, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: April 11)

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-JAN 16, 2025 Minutes for Approval-FEB 20, 2025 Minutes for Approval-MAR 20, 2025 1b RES Adopt Amendment to Purchasing
Policy (Koehn)
Receive Draft Financials: JAN 2025
(Koehn)
Receive Draft Financials: FEB 2025
(Koehn)
1c Draft FY 2024-25 Quarterly Financial
Reports through December 31, 2024
(Koehn)
AMI audit (Koehn) Contracts for renewal per Purchasing
Policy (Koehn)
1d RES authorizing an increase of staffing
positions by one to a total of 22 full
time staffing positions (Koehn)
Amendment to Uncollectible Accounts
Policy (Koehn)
1e Affirm Committee Members for 2025
(Eckert)
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)
Regular 2 Appoint Committee Members for
2025 (action-Eckert)
ICE Energy (discussion- Stassi-Vanacore)
guest
Legislative Platform
(discussion-Kang) guest
RES Revised NEM Policy
(action-Koehn)
3 RES Marketing Contract
(action - Stassi-Vanacore) guest
RES Amendment to RES 2023-33 Feed-in Tariff (FiT) re: adding Biomass NEM and solar + storage (action-Kang)
4 RES approving Amendment No. 6 to
the Amended & Restated JPA –
administrative (action-Eckert)
RES Toolkit program
(action- Stassi-Vanacore)
5 RES approving Amendment No. 7 to
the Amended & Restated JPA -
Membership (action-Eckert)
State of the Utility (discussion-Eckert)
6 RES approving Addendum No. 3 to the
Community Choice Aggregation
Implementation Plan & Statement of
Intent (action-Eckert)
7 RES GridGen Expansion
(action- Stassi-Vanacore) guest
General Function II Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs;
QTRLY Updates: Strategic Plan
Objectives; Sponsorship Activity
Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs;
Chief Executive Officer’s Report
REG Reports: Leg/Reg;
Communications; Programs;
QTRLY Updates: 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
Board Workshop (discussion-Eckert)
I
7 17
-
r---7
I I
Agenda Planning Document – Pioneer Community Energy Updated 02-21-2025 AUDIT/FINANCE COMMITTEE TO BE SCHEDULED – EARLY MAY
in-person & remote locations IN THE FUTURE
Greg Janda, Chair
Gary Petersen
David Ring
vacancy
o Budget
o Facilities

ENERGY PROCUREMENT REVIEW
AD HOC COMMITTEE TO BE SCHEDULED – EARLY MARCH
zoom only

IN THE FUTURE
Greg Janda, Chair
Gary Petersen, Vice Chair
Alice Dowdin Calvillo
vacancy
o Review of EPRC Authority in Approval of Long-Term PPAs o Approve long-term PPAs

EXPANSION
AD HOC COMMITTEE TO BE SCHEDULED – APRIL / EARLY MAY
zoom only

IN THE FUTURE
Alice Dowdin Calvillo, Chair
vacancy
vacancy
GOVERNANCE COMMITTEE TO BE SCHEDULED – PRIOR TO MARCH 20 in-person & remote locations IN THE FUTURE
Board Chair
Board Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o Timing of installing Board Members for the Expansion
Territories
o Introduction of the Compensation Study

COMMUNITY ADVISORY COMMITTEE

TO THE CHIEF EXECUTIVE OFFICER
FEBRUARY 26, 2025 IN THE FUTURE
Meets on the 4th Wednesday
(even-numbered months)
7

Attachment 2: Legislative and Regulatory Update
Date: 2/27/2025

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.
• Pioneer is planning a Lobby Day on February 26, 2025 to introduce our organization to our new constituent representatives including Assemblymembers Heather Hadwick and David Tangipa and Senator Christopher Cabaldon. Pioneer will also meet with our existing delegation members to brief them on our legislative priorities in the 2025 session, and garner support for our policy initiatives. • Pioneer is planning a Legislator Biomass Education Tour at Sierra Pacific Industries in Lincoln, CA on March 7, 2025. Legislators will have the opportunity to tour a biomass facility and learn about the importance of biomass in producing renewable and reliable energy, while maintaining our forest health and protecting our communities from wildfire risk.

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
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
Plf)NEER

COMMUNITY ENERGY
Attachment 2 Agenda Date: 2/27/2025

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; 2025
ERRA Forecast Application
Reduce the ERRA impact on the
PCIA; increase data transparency
from the IOUs
R.21-03-011 Provider of Last Resort (POLR)
Order Instituting Rulemaking
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 - OIR – 21-OIR-03, 23-
LMS-01
Load Management Standards (LMS) Ensure Pioneer maintains compliance with CEC mandates and
requirements
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. • 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.

Attachment 2 Agenda Date: 2/27/2025

• 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.

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 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 on the CPUC’s 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 Attachment 2 Agenda Date: 2/27/2025

recommendation to increase the growth of biomass.

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.
• 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 Attachment 2 Agenda Date: 2/27/2025

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 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 Attachment 2 Agenda Date: 2/27/2025

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.

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 Attachment 2 Agenda Date: 2/27/2025

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.
• 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).

Attachment 2 Agenda Date: 2/27/2025

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 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”.

Attachment 2 Agenda Date: 2/27/2025

• 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 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 Attachment 2 Agenda Date: 2/27/2025

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 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.

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.

Attachment 2 Agenda Date: 2/27/2025

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. 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- Attachment 2 Agenda Date: 2/27/2025

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 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.

Attachment 2 Agenda Date: 2/27/2025

• 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. • 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.
1 Attachment 3 Communications and Outreach Updates
Date: 2/27/2025
NOTABLE ACHIEVEMENTS – JANUARY 2025:

OUTREACH AND ENGAGEMENT
In addition to routine outreach, additional efforts focused on expansion and meetings with prospective expansion communities.
• Rocklin Chamber of Commerce Breakfast
• Placer County Association of Realtors (PCAR) Presentation, Auburn • Rocklin Chamber of Commerce Board of Directors Meeting • Expansion: briefing with Nevada County staff
• Expansion: briefing with the City of Live Oak Interim City Manager • Expansion: Town of Paradise Council presentation
• Expansion: Live Oak City Council, First Reading
• Expansion: Tuolumne County Supervisors briefings (2)
• Expansion: City of Oroville City Council, First Reading • Expansion: Yuba City Council, presentation of IAS Findings, First Reading • Expansion: Nevada County Supervisor Workshop for New Board Members • Expansion: Butte County Supervisors, First Reading
• Expansion: Sutter County Supervisors presentation
• Expansion: Glenn County Supervisors, First Reading
• Expansion: Willows City Council presentation
• Expansion: City of Chico City Council, First Reading

SOCIAL MEDIA
January social media activity was steady, continued growth in both followers and engagement • Significant traction came from news stories about expansion and drove increased social media engagement.
• January brought an uptick in engagement from CalCCA on all platforms, which reposted or commented on several of Pioneer’s posts, especially on LinkedIn. This, in turn, generated increased engagement in Pioneer’s posts.
• Expansion discussions and presentations allow for
early relationship building and the anticipated
approval of Pioneer expansion into all 13
prospective territories.
• The potential expansion of service into 13 new
territories created significant outreach and earned
media opportunities.
• Pioneer was featured in several print and television
stories, including in the opinion-leader Sacramento
Bee and CBS13.

Pioneer Community Energy Board Chair Alice
Dowdin Calvillo’s interview on CBS13 aired on
three different newscasts on January 30
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COMMUNITY ENERGY

• The conversation also included inquiry about expansion plans for Amador. • Top performing posts include National Energy Assistance Day (LinkedIn), Celebrate the Savings (Facebook), and Savings Tip Tuesday Bingo (Instagram).

CUSTOMER COMMUNICATIONS/CALL CENTER
With 549 calls, the call center activity increased by 63 percent from December to January. • The most frequent inquiries were about billing (16.25%) and NEM (15.35%). • One-third of all calls came from El Dorado County, and 21% of calls were from unverified accounts.
• A total of 9 re-enrollments during January.
• Pioneer receive a 97.2% satisfaction rate with 108 surveys completed.

The chatbot has a total of 281 interactions in January. • 42 live conversations (up 110% from December).
o Average of two conversations a day.
o January 31 had the most live conversations (6)
• Satisfaction rate of 4.8/5.

WEBSITE
Website traffic mirrored call center activity, with the Residential Rates and About Us pages receiving greater than usual traffic. Traffic also spiked after our presentation in Yuba City and the subsequent media coverage. Much of the traffic came from “referral,” which means visitors came to our site after clicking a link from another site. This trend also corresponds to the recent media coverage.
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Attachment 4: Program Updates
Date: 2/27/2025

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

GridGen (solar + storage)
• 55 customers in the active pipeline
• 4 have reached PTO
• 2 additional customers will reach PTO in Q1 of 2025
• 11 additional customers have signed contracts
• Proposed program expansion on Board agenda for February 27, 2025, meeting 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 Q1 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) • PG&E approved agreement on February 14, 2025.
• 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 on February 26, 2025. • Topic includes receive a presentation on the Ice Energy program.

Plf)NEER

COMMUNITY ENERGY
PG&E Rate Pioneer Rate Time of Use Period
Pioneer Rates
(Gen Only)
E-1
EL-1
EM
EML
ES
ESL
ESR
ESRL
ET
ETL
E-1** E-1-P All 0.13217
SUMMER PEAK 0.30697
SUMMER PART-PEAK 0.16924
EV-A SUMMER OFF-PEAK 0.12471
EV-B WINTER PEAK 0.12028
WINTER PART-PEAK 0.09642
(E Vehicles) WINTER OFF-PEAK 0.09642
SUMMER PEAK 0.19614
SUMMER PART-PEAK 0.15322
EV-2 SUMMER OFF-PEAK 0.11372
WINTER PEAK 0.14154
WINTER PART-PEAK 0.12955
(E Vehicles) WINTER OFF-PEAK 0.10701
SUMMER PEAK 0.24971
E-TOU-B SUMMER OFF-PEAK 0.13158
EL-TOU-B WINTER PEAK 0.14795
WINTER OFF-PEAK 0.11071
SUMMER PEAK 0.20329
SUMMER Off-PEAK 0.12361
WINTER PEAK 0.14564
WINTER Off-PEAK 0.12003
SUMMER PEAK 0.21253
SUMMER Off-PEAK 0.11177
WINTER PEAK 0.17330
WINTER Off-PEAK 0.13962
SUMMER PEAK 0.26981
SUMMER PART-PEAK 0.17466
SUMMER OFF-PEAK 0.13137
WINTER PEAK 0.11416
WINTER PART-PEAK 0.09499
WINTER OFF-PEAK 0.08218
Pioneer Community Energy
Electric Generation Rate Schedules

RESIDENTIAL CUSTOMERS
E-1 All 0.13768

E-ELEC E-ELEC
EV
EV-2

E-TOU-B
E-TOU-C3 E-TOU-C3

E-TOU-D E-TOU-D
1 PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
A-1-A A-1-A SUMMER 0.15164
WINTER 0.11310
A-1-A** A-1-A-P SUMMER 0.14557
WINTER 0.10858
SUMMER
PEAK 0.15422
PART-PEAK 0.15422
A-1-B A-1-B OFF-PEAK 0.13050
WINTER
PART-PEAK 0.12470
OFF-PEAK 0.12414
SUMMER
PEAK 0.14805
PART-PEAK 0.14805
A-1-B** A-1-B-P OFF-PEAK 0.12528
WINTER
PART-PEAK 0.11971
OFF-PEAK 0.11917
SUMMER
PEAK 0.19289
PART-PEAK 0.14563
B-1 B-1 OFF-PEAK 0.12565
WINTER
PEAK 0.13985
OFF-PEAK 0.12437
SUPER OFF-PEAK 0.10861
SUMMER
PEAK 0.19751
PART-PEAK 0.15675
B-1-ST B-1-ST OFF-PEAK 0.12243
WINTER
PEAK 0.14896
PART-PEAK 0.13538
OFF-PEAK 0.11599
SUPER OFF-PEAK 0.10023
SUMMER
PEAK 0.16754
PART-PEAK 0.16754
A-6 A-6 OFF-PEAK 0.13514
WINTER
PART-PEAK 0.12614
OFF-PEAK 0.12546
SUMMER
PEAK 0.16084
PART-PEAK 0.16084
A-6** A-6-P OFF-PEAK 0.12973
WINTER
PART-PEAK 0.12109
OFF-PEAK 0.12044
SUMMER
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
1 I I I I

I I I I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
PEAK 0.28250
OFF-PEAK 0.11937
B-6 B-6 WINTER
PEAK 0.14770
OFF-PEAK 0.10973
SUPER OFF-PEAK 0.07510
SUMMER 0.15198
A-10-A-S A-10-A WINTER 0.13109

0.00000
SUMMER 0.13156
A-10-A-P A-10-A-P WINTER 0.11349

0.00000
SUMMER
PEAK 0.16519
PART-PEAK 0.16519
OFF-PEAK 0.13948
A-10-B-S A-10-B WINTER
PART-PEAK 0.13195
OFF-PEAK 0.13127

0.00000
SUMMER
PEAK 0.14547
PART-PEAK 0.14547
OFF-PEAK 0.12116
A-10-B-P A-10-B-P WINTER
PART-PEAK 0.11404
OFF-PEAK 0.11340

0.00000
SUMMER
PEAK 0.21857
PART-PEAK 0.15935
B-10-S B-10-S OFF-PEAK 0.12808
WINTER
PEAK 0.16286
OFF-PEAK 0.12879
SUPER OFF-PEAK 0.09391
SUMMER
PEAK 0.19676
PART-PEAK 0.14079
B-10-P B-10-P OFF-PEAK 0.11119
WINTER
PEAK 0.14432
OFF-PEAK 0.11202
SUPER OFF-PEAK 0.07714
SUMMER
PEAK 0.17305
PART-PEAK 0.11858
B-10-T B-10-T OFF-PEAK 0.08971
WINTER
PEAK 0.12212
OFF-PEAK 0.09061
DEMAND CHARGE ($/KW)SUMMER MAX
DEMAND CHARGE ($/KW)SUMMER MAX
DEMAND CHARGE ($/KW)SUMMER MAX
DEMAND CHARGE ($/KW)SUMMER MAX
2 PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
SUPER OFF-PEAK 0.05572
SUMMER
PEAK 0.09399
PART-PEAK 0.09399
OFF-PEAK 0.08681
E-19-S, V E-19-S WINTER
PART-PEAK 0.08370
OFF-PEAK 0.08285
PEAK 16.61000
PART-PEAK 16.61000
SUMMER
PEAK 0.08049
PART-PEAK 0.08049
OFF-PEAK 0.07354
E-19-P, V E-19-P WINTER
PART-PEAK 0.07054
OFF-PEAK 0.06972
PEAK 14.77000
PART-PEAK 14.77000
SUMMER
PEAK 0.07197
PART-PEAK 0.07197
OFF-PEAK 0.06479
E-19-T, V E-19-T WINTER
PART-PEAK 0.06171
OFF-PEAK 0.06087
PEAK 16.74000
PART-PEAK 16.74000
SUMMER
PEAK 0.16236
PART-PEAK 0.16236
E-19-R-S, V-R-S E-19-R-S OFF-PEAK 0.13054
WINTER
PART-PEAK 0.12805
OFF-PEAK 0.12737
SUMMER
PEAK 0.13874
PART-PEAK 0.13874
E-19-R-P, V-R-P E-19-R-P OFF-PEAK 0.11056
WINTER
PART-PEAK 0.10819
OFF-PEAK 0.10755
SUMMER
PEAK 0.13327
PART-PEAK 0.13327
E-19-R-T, V-R-T E-19-R-T OFF-PEAK 0.10864
WINTER
PART-PEAK 0.10631
OFF-PEAK 0.10567
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
3 I
I
I
I
I
I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
SUMMER
PEAK 0.17436
PART-PEAK 0.12277
OFF-PEAK 0.08628
WINTER
PEAK 0.14160
B-19-S B-19-S OFF-PEAK 0.08614
SUPER OFF-PEAK 0.01174
PEAK 25.93000
PART-PEAK 3.77000
PEAK 3.07000
SUMMER
PEAK 0.14728
PART-PEAK 0.10808
OFF-PEAK 0.07399
WINTER
PEAK 0.12449
B-19-P B-19-P OFF-PEAK 0.07442
SUPER OFF-PEAK 0.00318
PEAK 21.80000
PART-PEAK 3.20000
PEAK 2.24000
SUMMER
PEAK 0.13063
PART-PEAK 0.11403
OFF-PEAK 0.07868
WINTER
PEAK 0.12951
B-19-T B-19-T OFF-PEAK 0.07946
SUPER OFF-PEAK 0.00583
PEAK 19.55000
PART-PEAK 4.89000
PEAK 1.88000
SUMMER
PEAK 0.28351
PART-PEAK 0.15337
B-19-R-S B-19-R-S OFF-PEAK 0.11640
WINTER
PEAK 0.15696
OFF-PEAK 0.11633
SUPER OFF-PEAK 0.08194
SUMMER
PEAK 0.24995
PART-PEAK 0.13135
B-19-R-P B-19-R-P OFF-PEAK 0.09738
WINTER
PEAK 0.13363
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)WINTER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)WINTER
DEMAND CHARGE ($/KW)WINTER
DEMAND CHARGE ($/KW)SUMMER
4 I
I I
I
I I
I
I I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
OFF-PEAK 0.09749
SUPER OFF-PEAK 0.06310
SUMMER
PEAK 0.21935
PART-PEAK 0.14111
B-19-R-T B-19-R-T OFF-PEAK 0.10064
WINTER
PEAK 0.13318
OFF-PEAK 0.10085
SUPER OFF-PEAK 0.06646
SUMMER
PEAK 0.28351
PART-PEAK 0.15337
B-19-S-S B-19-S-S OFF-PEAK 0.11640
WINTER
PEAK 0.15696
OFF-PEAK 0.11633
SUPER OFF-PEAK 0.08194
SUMMER
PEAK 0.24995
PART-PEAK 0.13135
B-19-S-P B-19-S-P OFF-PEAK 0.09738
WINTER
PEAK 0.13363
OFF-PEAK 0.09749
SUPER OFF-PEAK 0.06310
SUMMER
PEAK 0.21935
PART-PEAK 0.14111
B-19-S-T B-19-S-T OFF-PEAK 0.10064
WINTER
PEAK 0.13318
OFF-PEAK 0.10085
SUPER OFF-PEAK 0.06646
SUMMER
PEAK 0.08870
PART-PEAK 0.08870
OFF-PEAK 0.08165
E-20-S E-20-S WINTER
PART-PEAK 0.07857
OFF-PEAK 0.07772
PEAK 15.78000
PART-PEAK 15.78000
SUMMER
PEAK 0.08832
PART-PEAK 0.08832
OFF-PEAK 0.08133
E-20-P E-20-P WINTER
PART-PEAK 0.07834
OFF-PEAK 0.07752
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
5 I I I I
I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
PEAK 17.25000
PART-PEAK 17.25000
SUMMER
PEAK 0.07659
PART-PEAK 0.07659
OFF-PEAK 0.06959
E-20-T E-20-T WINTER
PART-PEAK 0.06658
OFF-PEAK 0.06577
PEAK 21.33000
PART-PEAK 21.33000
SUMMER
PEAK 0.15029
PART-PEAK 0.15029
E-20-R-S E-20-R-S OFF-PEAK 0.12113
WINTER
PART-PEAK 0.11865
OFF-PEAK 0.11797
SUMMER
PEAK 0.14583
PART-PEAK 0.14583
E-20-R-P E-20-R-P OFF-PEAK 0.11554
WINTER
PART-PEAK 0.11317
OFF-PEAK 0.11253
SUMMER
PEAK 0.13932
PART-PEAK 0.13932
E-20-R-T E-20-R-T OFF-PEAK 0.10936
WINTER
PART-PEAK 0.10703
OFF-PEAK 0.10639
SUMMER
PEAK 0.16631
PART-PEAK 0.12204
OFF-PEAK 0.08364
WINTER
PEAK 0.13879
B-20-S B-20-S OFF-PEAK 0.08334
SUPER OFF-PEAK 0.00905
PEAK 24.26000
PART-PEAK 3.52000
PEAK 3.09000
SUMMER
PEAK 0.16352
PART-PEAK 0.11382
OFF-PEAK 0.07916
WINTER
PEAK 0.13188
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)WINTER
6 I I I I
I
I
I
I
I
I I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
B-20-P B-20-P OFF-PEAK 0.07925
SUPER OFF-PEAK 0.00458
PEAK 27.16000
PART-PEAK 3.73000
PEAK 3.13000
SUMMER
PEAK 0.14164
PART-PEAK 0.10980
OFF-PEAK 0.07425
WINTER
PEAK 0.13310
B-20-T B-20-T OFF-PEAK 0.06883
SUPER OFF-PEAK 0.00463
PEAK 28.89000
PART-PEAK 6.88000
PEAK 3.86000
SUMMER
PEAK 0.27175
PART-PEAK 0.14431
B-20-R-S B-20-R-S OFF-PEAK 0.10835
WINTER
PEAK 0.15020
OFF-PEAK 0.10822
SUPER OFF-PEAK 0.07390
SUMMER
PEAK 0.25944
PART-PEAK 0.13570
B-20-R-P B-20-R-P OFF-PEAK 0.10238
WINTER
PEAK 0.14090
OFF-PEAK 0.10243
SUPER OFF-PEAK 0.06811
SUMMER
PEAK 0.25712
PART-PEAK 0.14325
B-20-R-T B-20-R-T OFF-PEAK 0.09501
WINTER
PEAK 0.14309
OFF-PEAK 0.09220
SUPER OFF-PEAK 0.06072
SUMMER
PEAK 0.27175
PART-PEAK 0.14431
B-20-S-S B-20-S-S OFF-PEAK 0.10835
WINTER
PEAK 0.15020
OFF-PEAK 0.10822
SUPER OFF-PEAK 0.07390
DEMAND CHARGE ($/KW)WINTER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)WINTER
7 I
I I
I
I I
PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
SUMMER
PEAK 0.25944
PART-PEAK 0.13570
B-20-S-P B-20-S-P OFF-PEAK 0.10238
WINTER
PEAK 0.14090
OFF-PEAK 0.10243
SUPER OFF-PEAK 0.06811
SUMMER
PEAK 0.25712
PART-PEAK 0.14325
B-20-S-T B-20-S-T OFF-PEAK 0.09501
WINTER
PEAK 0.14309
OFF-PEAK 0.09220
SUPER OFF-PEAK 0.06072
SUMMER
PEAK 0.19953
PART-PEAK 0.15959
STANDBY - S STOUS OFF-PEAK 0.10730
WINTER
PART-PEAK 0.16595
OFF-PEAK 0.12545

0.98000
SUMMER
PEAK 0.19953
PART-PEAK 0.15959
STANDBY - P STOUP OFF-PEAK 0.10730
WINTER
PART-PEAK 0.16595
OFF-PEAK 0.12545

0.98000
SUMMER
PEAK 0.12753
PART-PEAK 0.09998
STANDBY - T STOUT OFF-PEAK 0.06353
WINTER
PART-PEAK 0.10431
OFF-PEAK 0.07632

0.67000
SUMMER
PEAK 0.13024
PART-PEAK 0.11844
OFF-PEAK 0.10532

S-B-S S-B-S WINTER
PEAK 0.12552
OFF-PEAK 0.10643
SUPER OFF-PEAK 0.06405

1.32000
SUMMER
PEAK 0.13024
PART-PEAK 0.11844
RESERVATION CHARGE ($/KW)
RESERVATION CHARGE ($/KW)
RESERVATION CHARGE ($/KW)
RESERVATION CHARGE ($/KW)
8 PG&E Rate Pioneer Rate
Time of Use
Period
Pioneer Rates
(Gen Only)
Pioneer Community Energy
Electric Generation Rate Schedules

COMMERCIAL, INDUSTRIAL AND GENERAL SERVICE CUSTOMERS
OFF-PEAK 0.10532

S-B-P S-B-P WINTER
PEAK 0.12552
OFF-PEAK 0.10643
SUPER OFF-PEAK 0.06405

1.32000
SUMMER
PEAK 0.10849
PART-PEAK 0.09700
OFF-PEAK 0.08421

S-B-T S-B-T WINTER
PEAK 0.10398
OFF-PEAK 0.08540
SUPER OFF-PEAK 0.04295

0.62000
SUMMER
ON-Peak 0.27637
OFF-PEAK 0.10111
SUPER OFF-PEAK 0.07674
BEV1 BEV1 WINTER
PART-PEAK 0.27637
OFF-PEAK 0.10111
SUPER OFF-PEAK 0.07674
SUMMER
ON-Peak 0.29397
OFF-PEAK 0.09875
BEV2S BEV2S SUPER OFF-PEAK 0.07436
WINTER
PART-PEAK 0.29397
OFF-PEAK 0.09875
SUPER OFF-PEAK 0.07436
SUMMER
ON-Peak 0.28401
OFF-PEAK 0.09587
BEV2P BEV2P SUPER OFF-PEAK 0.07263
WINTER
PART-PEAK 0.28401
OFF-PEAK 0.09587
SUPER OFF-PEAK 0.07263
RESERVATION CHARGE ($/KW)
RESERVATION CHARGE ($/KW)
9 PG&E Rate Pioneer Rate Time of Use Period
Pioneer
Rates (Gen
Only)
SUMMER 0.10957
AG-1-A AG-1-A WINTER 0.09667

4.17000
SUMMER 0.11857
AG-1-B AG-1-B WINTER 0.08150

5.51000
SUMMER
PEAK 0.10894
OFF-PEAK 0.10894

AG-RA AG-RA WINTER
PART-PEAK 0.09300
OFF-PEAK 0.09232

2.82000
SUMMER
PEAK 0.09512
OFF-PEAK 0.09512
WINTER
AG-RB AG-RB PART-PEAK 0.08418
OFF-PEAK 0.08349
MAX 3.98000
PEAK 0.00000
SUMMER
PEAK 0.10412
OFF-PEAK 0.10412

AG-VA AG-VA WINTER
PART-PEAK 0.08950
OFF-PEAK 0.08882

2.97000
SUMMER
PEAK 0.09083
OFF-PEAK 0.09083
WINTER
AG-VB AG-VB PART-PEAK 0.07891
OFF-PEAK 0.07891
MAX 3.77000
PEAK 0.00000
SUMMER
PEAK 0.10626
OFF-PEAK 0.10626
AG-4-A AG-4-A WINTER
AG-4-D PART-PEAK 0.09256
OFF-PEAK 0.09187

2.90000
SUMMER
PEAK 0.11882
DEMAND CHARGE ($/KW)SUMMER MAX
Pioneer Community Energy
Electric Generation Rate Schedules

AGRICULTURAL CUSTOMERS
CONNECTED LOAD ($/HP)SUMMER MAX
CONNECTED LOAD ($/HP)SUMMER
DEMAND CHARGE ($/KW)SUMMER
CONNECTED LOAD ($/HP)SUMMER
DEMAND CHARGE ($/KW)SUMMER
CONNECTED LOAD ($/HP)SUMMER
1 I
I
I
PG&E Rate Pioneer Rate Time of Use Period
Pioneer
Rates (Gen
Only)
Pioneer Community Energy
Electric Generation Rate Schedules

AGRICULTURAL CUSTOMERS
OFF-PEAK 0.11882
AG-4-B WINTER
AG-4-E AG-4-B PART-PEAK 0.10539
OFF-PEAK 0.10473
MAX 5.05000
PEAK 0.00000
SUMMER
PEAK 0.09049
PART-PEAK 0.09049
OFF-PEAK 0.07974
AG-4-C AG-4-C WINTER
AG-4-F PART-PEAK 0.07725
OFF-PEAK 0.07657
PEAK 5.33000
PART-PEAK 5.33000
SUMMER
PEAK 0.11509
OFF-PEAK 0.11509
AG-5-A AG-5-A WINTER
AG-5-D PART-PEAK 0.10330
OFF-PEAK 0.10262

8.03000
SUMMER
PEAK 0.09823
OFF-PEAK 0.09823
AG-5-B WINTER
AG-5-E AG-5-B PART-PEAK 0.09148
OFF-PEAK 0.09083
MAX 9.79000
PEAK 0.00000
SUMMER
PEAK 0.07851
PART-PEAK 0.07851
OFF-PEAK 0.07268
AG-5-C AG-5-C WINTER
AG-5-F PART-PEAK 0.07020
OFF-PEAK 0.06952
PEAK 10.99000
PART-PEAK 10.99000
SUMMER
PEAK 0.24584
AG-A1 AG-A1 OFF-PEAK 0.13095
WINTER
PEAK 0.12776
OFF-PEAK 0.10237
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
CONNECTED LOAD ($/HP)SUMMER
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
2 I
I
I
I
I
PG&E Rate Pioneer Rate Time of Use Period
Pioneer
Rates (Gen
Only)
Pioneer Community Energy
Electric Generation Rate Schedules

AGRICULTURAL CUSTOMERS
SUMMER
PEAK 0.24584
AG-A2 AG-A2 OFF-PEAK 0.13095
WINTER
PEAK 0.12776
OFF-PEAK 0.10237
SUMMER
PEAK 0.26696
AG-B AG-B OFF-PEAK 0.14881
WINTER
PEAK 0.14369
OFF-PEAK 0.11853
SUMMER
PEAK 0.11416
OFF-PEAK 0.08586

AG-C AG-C WINTER
PEAK 0.10010
OFF-PEAK 0.07560
MAX 21.60000
SUMMER
PEAK 0.21189
AG-FA AG-FA OFF-PEAK 0.13784
WINTER
PEAK 0.12805
OFF-PEAK 0.10266
SUMMER
PEAK 0.23568
AG-FB AG-FB OFF-PEAK 0.15763
WINTER
PEAK 0.14605
OFF-PEAK 0.12066
SUMMER
PEAK 0.12380
OFF-PEAK 0.09499

AG-FC AG-FC WINTER
PEAK 0.10996
OFF-PEAK 0.08457
MAX 21.60000
DEMAND CHARGE ($/KW)SUMMER
DEMAND CHARGE ($/KW)SUMMER
3 I
I
I
I I
I
I
I
PG&E Rate Pioneer Rate Time of Use Period
Pioneer Rates
(Gen Only)
LS-1
LS-2
LS-3
OL-1
TC-1 TC-1 All 0.11831
Pioneer Community Energy
Electric Generation Rate Schedules

STREET AND OUTDOOR LIGHTING
STREET LIGHTING All 0.11259
1 FY 2025-2027 Strategic Plan
Quarterly Progress Report
CEO Report
February 27, 2025
FY 2025-2027 Strategic Plan
• The plan was adopted in September 2024
• Five (5) Strategic Goals to support the
Mission and Vision

1. Be a Community Partner

2. Be Fiscally Strong & Resilient

3. Provide Exceptional Customer Service

4. Achieve Operational Optimization

5. Be a Great Place to Work
• Quarterly report will provide progress
towards each goal and highlights for next
quarter
Summary
Community
Partner
Fiscally
Strong &
Resilient
Exceptional
Customer
Service
100
Operational
Optimization
Great Place to
Work
Overall
Be a Community Partner
• Progress Fiscal Year to Date:
Continue to maintain a participation rate of >95%
with Nevada City and Grass Valley
Stable participation rate in balance of territory
Maintain presence with Member’s Chamber of
Commerce and Rural County Representatives of
California
• Highlights this Quarter
Lobby Day with introduction of bill(s) to support
biomass
Hiring of Marketing Consultant
Expand GridGen program and launch Toolkit
program
Be Fiscally Strong & Resilient
• Progress Fiscal Year to Date:
Great financial audit
Continue to build reserves towards an “A” rating
• Highlights this Quarter
 Review Mid-Year Budget
 Complete filing with CPUC for expansion of
thirteen (13) new communities
 Negotiating seven (7) long-term power purchase
agreements including biomass
 Negotiating biomass projects in our service
territory
 Evaluate Feed-In Tariff for possible expansion of
scope to include solar plus storage
Provide Exceptional Customer
Service
• Progress Fiscal Year to Date
 Set rates to achieve an average discount of 10%
in the service territory for 2025
 Continue to respond to customer phone calls in a
timely and accurate manner
 Have received an uptick in Google reviews due to
our courteous and professional manner
 Launched webinars on issues that matter to our
customers
• Highlights this Quarter
Continuous improvements to the website
Planning out communications outreach after
expansion
Achieve Operational
Optimization
• Progress Fiscal Year to Date
 Revenue sharing on battery optimization with
Yellowpine project has netted $1.4 million
 $1.5 million in revenue from sale of large hydro
allocations
• Highlights this Quarter
 Completion of Automated Meter Infrastructure IT
Audit (required by the CPUC) completed
 Continued work on using cQuant Analytics to
improve forecasting and evaluation of power
purchases
Be a Great Place to Work
• Progress Fiscal Year to Date
 Active in recruitments with 100% of positions
filled by March 2025
 Quarterly volunteering at Feeding the Foothills and
well ahead of 100 hours per year volunteer target
 Conduct team building events
• Highlights this Quarter
 Conduct annual employee survey
 Launch triennial compensation study
 Review health and welfare benefits as part of the
budget process
 Support volunteer activities within the community
 Onboard new employees
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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.