Pioneer Community Energy Board of Directors
September 17, 2026

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 9/17/2026

PERSONNEL
I am pleased to introduce to the Board our newest employees:

1. Haagen Woodford – Haagen joined our team as the Customer Care Coordinator in June. Haagen is a long-time resident of the region with a proven track record of delivering exceptional customer experiences and building strong, lasting relationships.

Before joining Pioneer, Haagen worked at CarMax, where he consistently earned 5-star customer satisfaction ratings including ranking No. 1 among more than 2,250 sales associates throughout the nation.

Haagen graduated with honors from California State University, Sacramento, with a bachelor’s degree in economics.

2. Jonathan (“Jon”) Hart – Jon joined our team as the Manager of Legislative and Regulatory Affairs in July.

Jon brings many years of experience and has expertise in California’s regulatory and legislative agencies and processes. Most recently, Jon was the Policy Director for the California Solar and Storage Association and has worked for clean energy developers and non-profits. Jon has worked on a wide range of regulatory and legislative issues, such as clean energy program development and implementation, demand response, behind-the-meter battery integration into CAISO markets, electric vehicle charging, and building code development.

Jon has a Masters in Energy Law and Policy from the Vermont Law School.

Current Recruitments
Staff have begun interviews for the Community Outreach Specialist positions. The goal is to fill all five positions by the end of the calendar year.

Staff have begun the resume screening process for the Chief Human Resources Officer. Interviews are expected to begin later this month or early October.

DIABLO CANYON NUCLEAR POWER PLANT TOUR
The tour date is set for September 21st. Directors Carter, Pearl, and Ring will be attending.

Staff will investigate options for another tour in Spring 2027 and include Board Directors from our expansion territories.

LEGISLATIVE UPDATE
Pioneer’s biomass bill to create the FOREST Fund, AB 706 (Aguier0Curry), passed out of the legislature and awaits the governor’s signature. This is a major victory for Pioneer as the bill passed on a unanimous bipartisan basis and the final version contains the major provisions that we needed.

Plf)NEER

COMMUNITY ENERGY
Agenda Item: IV-B Agenda Date: 9/17/2026

For more information on this and other legislative updates, please refer to the Legislative and Regulatory Report (see Attachment 2).

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) The following agreements have been conducted by the Chief Executive Officer, consistent with the authority delegated by the Board:
 Amendment No. 2 to June 17, 2021, Agreement with Braun, Blaising & Wynne, adding Section 3, “Fees and Description of Services,” listing hourly rates for individual client services, effective August 1, 2026.

No change in budget.
 Single Work Order with Tricorp-Group, Inc. for mini split installation of a 20-ton Fujitsu ductless A/C system in the IT room at 2540 Warren Drive, in the amount of $20,423.00, effective August 10, 2026.  Framework Services Contract with Aurora for Subscription Analytics Services and Subscription Analytics Services Supplement No. 1, in the amount of $15,000 per year, effective August 10, 2026.  CIVICPLUS DocAccess program meeting accessibility requirements for all documents posted to Pioneer’s website, in the amount of $12,380.00 for implementation plus 2 years of service, effective September 1, 2026.

NEVADA COUNTY FAIR
Pioneer staffed a booth for the Nevada County Fair. Our presence was well received with multiple comments from Nevada County residents wishing for a sooner enrollment into Pioneer. Staff also enrolled those interested in our various program offerings.

This summer, Pioneer hosted a booth at all three County Fairs that are part of our service territory. (Gentleman enjoying a snack while spinning the wheel at our booth at the Nevada County Fair) Agenda Item: IV-B Agenda Date: 9/17/2026

VOLUNTEER HOURS FOR FISCAL YEAR 2025-26
Pioneer identifies the importance of volunteer activity in the strategic plan with a goal of 100 volunteer hours from staff per fiscal year. I am proud to report for Fiscal Year 2025-26 staff exceeded the goal and continue to focus on volunteer activities whenever possible.
(Staff at Feeding the Foothills – August 2026)

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

August 2026
July 2026
Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
San Diego Gas & Electric Company 8/12/2026 Buy Resource Adequacy - System 10/1/2026 10/31/2026 $85,250 ConocoPhillips Company 8/13/2026 Buy Energy - Unspecified Source 9/14/2026 9/30/2026 $418,600 ConocoPhillips Company 8/13/2026 Buy Energy - Unspecified Source 10/1/2026 10/31/2026 $587,500 ConocoPhillips Company 8/13/2026 Buy Energy - Unspecified Source 11/1/2026 11/6/2026 $31,263 Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
Peninsula Clean Energy Authority 2/24/2026 Buy Resource Adequacy - Flex 1/1/2028 12/31/2028 $3,900,000 Shell Energy North America 7/9/2026 Buy Energy - Unspecified Source 7/15/2026 9/30/2026 $1,086,661 l .,,ut\1\\\\1\lh,. FEEO\NG _,.
il ., .. ,11\\1\lllh, FEEDING - '
-.
.:

Agenda Item: IV-B Agenda Date: 9/17/2026

CHIEF EXECUTIVE OFFICER POWER SUPPLY CONTRACTS EXECUTIED (NON-POWER SUPPLY) • Single Work Order with Tricorp-Group, Inc. for Mini split installation at IT room (20-ton Fujitsu ductless A/C system) at 2540 Warren Drive, effective August 10, 2026, in the amount of $20,423.00. • Amendment No. 2 to Agreement with Braun, Blaising & Wynne adding Section 3 “Fees and Description of Services” for individual client services and hourly rates as listed in the Amendment. • Agreement with CIVICPLUS for DocAccess program to meet accessibility requirements for all documents posted to the website, for a two-year term, effective September 1, 2026, in the amount of $12,380.00.

PRESENTATIONS AND RELEVANT MEETINGS ATTENDED BY THE CHIEF EXECUTIVE OFFICER

1. Participated in monthly CalCCA Board and Committee meetings

2. Participated in meeting with Vice Mayor Culleton from the Town of Paradise

3. Accompanied our Board Chair to a meeting with SACOG on large board governance ideas

4. Participated in quarterly Greater Sacramento Economic Council Board meeting

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 9-9-26

BOARD OF

DIRECTORS
SEPTEMBER 17, 2026

REGULAR MEETING
3:00 PM
(Post Agenda: September 11)
OCTOBER 15, 2026

REGULAR MEETING
3:00 PM
(Post Agenda: October 9)
NOVEMBER 12, 2026

SPECIAL & REGULAR

MEETING
2:30 PM
(Post Agenda: November 6)

IN THE FUTURE
Special Meeting Closed Session-Labor (CEO contract) JAN>JUL New Member orientation/ workshops
Regular Meeting DEC/JAN Regular Meeting & Public Hearing (2027 Rates)
Consent 1a Minutes for Approval-JULY 23, 2026 Minutes for Approval-SEP 17, 2026 Minutes for Approval-OCT 15, 2026 DEC/JAN RES Amendment No. 7 to the Employment Agreement for CEO Donald
Eckert (General Counsel)
1b Status of Unaudited Fiscal Year 2025-26
Financial Statements (Koehn)
Receive Draft Financials JUL-AUG 2026
(Koehn)
If no Financial Reports, prepare Notice
for the agenda packet (Koehn)
1c RES Approving an Updated MOU with
SDRMA (Koehn)
RES Sagent Contract Amendment
(Stassi-Vanacore)
RES Granicus contract extension (Stassi-Vanacore)
1d RES Power Content Label
(Kang)
RES Policy Amendments- (3) IT (Koehn)
1e RES Policy Amendments- (3) IT & (1) HR
(Koehn)
Presentation 2a
2b

2c
-Celebratory Toast
-Presentation (NewGen Strategies)
guest: Brian Dickman
-Presentation (Sagent)
guest: Brantly Payne ++
-Presentation
guest: Barry Broome
-Presentation (Calpine Grant Award)
guest: TBD
DEC RES Recognition of Board Members
leaving office (Eckert)
Regular 3

Communications Plan for Expansion
(discussion- Stassi-Vanacore)
Overview of Biogas Projects
(discussion-Kang)
guest
2026 End of Legislative & Regulatory
Session Successes (discussion-Kang)
guest: NPA
-Update on South Lake Tahoe (Eckert)
-PCIA Hedging/Reserves (Eckert)
-Economic Development Rates (Eckert)
4 RES Microgrid Incentive Program (MIP)
Update – 2 projects (action-Kang)
Proposed Administrative Changes to
the JPA & Approve 30-Day Notice
[DEC 17 vote] (action-Eckert)
RES Calpine contract amendment
(action- Stassi-Vanacore)
-RES Large Load Policy (Kang) -FY 28-30 Strategic Plan (Eckert) DEC ZGlobal Scholarship Program (Stassi- Vanacore)
5 RES approving Proposed Administrative
Changes to Bylaws [Amendment No. 8]
(action-Eckert)
DEC RES JPA Amendment No. 9
Administrative Changes (Eckert)
DEC State of the Power Markets (Kang)
6 RES Approving Code of Conduct Policy
for the Board of Directors (action-Eckert)
DEC/JAN (PH) RES Authorizing 2027 Rate
Adjustment effective [date] (Eckert)
7 Review of Unaudited Financials ending
June 2026 (discussion-Koehn)
JAN RES Approving 2027 Meeting
Schedule-Governing Board (Eckert)
8 JAN RES Approving 2027 Meeting
Schedules-Committees (Eckert)
JAN RES Establishing Ad Hoc EPRC &
Appointing Members for 2027 (Eckert)
General Function II Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Introduce personnel (2)
Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
QTRLY: Strategic Plan Objectives;
Sponsorship Activity
Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Chief Executive Officer’s Report
QTRLY Updates requested by the Board
JAN – APR – JULY – OCT  Strategic Plan Objectives  Sponsorship Activity Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
-
17 -
-
7 7
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 9-9-26

AUDIT/FINANCE COMMITTEE TO BE SCHEDULED
in-person & remote locations IN THE FUTURE
Gary Petersen, Chair
Richard Pearl, Vice Chair
Greg Janda
Sean Lomen
David Ring
o July 13, 2026 Minutes
o Review Financial Audit
o Review 2027 Rates
(2027) Select Officers
GOVERNANCE COMMITTEE OCTOBER 6, 2026 – 3:30 PM
in-person & remote locations TO BE SCHEDULED – PRIOR TO NOV 12 BOARD Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o August 6, 2026 Minutes
o Review Administrative Amendments to JPA & Bylaws
o Closed Session-Labor (CEO contract)

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE

TO BE SCHEDULED
zoom only IN THE FUTURE
Ryan Carter, Chair
Alice Dowdin Calvillo, Vice Chair
Anthony DeMattei
Sean Lomen
o Using Put Options as a PCIA Hedging (JAN-BOARD) EPRC Establishment & Appointment of Members (2027) (2027) Select Officers

EXPANSION

AD HOC COMMITTEE

TO BE SCHEDULED
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy, Vice Chair
Suzanne Jones
Lori Parlin
o Selection of Officers
o City of South Lake Tahoe
(2027) Select Officers

COMMUNITY ADVISORY COMMITTEE
TO THE CHIEF EXECUTIVE OFFICER OCTOBER 28, 2026 IN THE FUTURE Meets on the 4th Wednesday
(even-numbered months)

Attachment: 2 Legislative and Regulatory Update
Date: 9/17/2026

Legislative Affairs
• Pioneer’s biomass bill to create the FOREST Fund, AB 706 (Aguiar-Curry), passed out of the legislature and awaits the governor’s signature. This is a major victory for Pioneer as the bill passed on a unanimous bipartisan basis, and the final version of the bill contains the major provisions that we wanted. Below is a summary of major events during the legislative session. • The 2026 Legislative Session began on Monday, January 5, 2026, and ended on August 31, 2026.

Pioneer will continue to advocate for support of biomass development, but the budget and Cap and Invest funding shortfalls will limit any available funds available to support biomass. • Pioneer held its annual Lobby Day on February 10, 2026. Pioneer’s Staff, Board Chair, and Lobbyists met with ten state legislator offices including current and future constituent representatives, and broader biomass champions. Pioneer discussed its key legislative priorities for the upcoming year including affordability concerning the Power Charge Indifference Adjustment (PCIA) and ongoing biomass development efforts. Specifically, Pioneer asked for support on the PCIA Transparency bill, AB 1761 (Rogers) and the FOREST Fund Act, AB 706 (Aguiar-Curry). • April 16, 2026 – Pioneer staff presented the 2026 Legislative Policy and Platform to the Board of Directors. Staff received approval from the Board to take positions on the following high priority bills:
o “Support” position on AB 706 (Aguiar-Curry), AB 1761 (Rogers), AB 2266 (Schultz), SB 1138 (Padilla), SB 875 (Wiener)
o “Oppose” position on SB 1295 (Stern)
• May 29, 2026 – Following the deadline for each house to pass bills that were introduced in the first house and developments in the legislative session, Pioneer updated its active high priority bills accordingly:
o “Support” position on AB 706 (Aguiar-Curry), AB 1761 (Rogers), SB 1138 (Padilla) o “Oppose unless amended” position on SB 2383 (Zbur)
o Changes in Pioneer’s bill positions:
 SB 875 (Wiener) was removed because it was held in policy committee  SB 1295 (Stern) was removed due to our concerns being alleviated by amendments  AB 2266 (Schultz) was removed due to concerns over the ambiguity in language creating possible increased regulatory complexity
 SB 2383 (Zbur) was added due to concerning amendments • June 19, 2026 – Pioneer submitted a letter removing our “oppose unless amended” position, and taking a neutral position, on SB 2383 (Zbur), following the addition of amendments which addressed our concerns regarding jurisdictional issues.
• August 31, 2026 –Following the deadline for both houses to pass bills out of the Legislature, below are the results of Pioneer’s high priority bills. The Governor has until September 30, 2026 to sign or veto the bills on his desk.
o AB 706 (Aguiar-Curry): Passed out of the Legislature, on the Governor’s desk o AB 1761 (Rogers): Passed out of the Legislature, on the Governor’s desk o SB 1138 (Padilla): Held in Assembly Appropriations
Plf)NEER

COMMUNITY ENERGY
[Publish Date] Agenda Date: 9/17/2026

Regulatory Affairs
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. New updates are color-coded in green. More updates will follow at future Board meetings as regulatory proceedings and matters evolve.

Key Terms
CPUC- California Public Utilities Commission OIR- Order Instituting Rulemaking/ “Proceeding” CEC- California Energy Commission ALJ- Administrative Law Judge LSE- Load Serving Entity AL- Advice Letter
IOU- Investor-Owned Utility PD- Proposed Decision
CAISO- California Independent System Operator D.- Decision ED- Energy Division PfM- Petition for Modification
PG&E- Pacific Gas and Electric Company CalCCA- California Community Choice Association Table of Contents:
• BioMAT Implementation – R.18-07-003; R.22-10-010; R.24-01-017:........................................3 • California Climate Credit – R. 25-07-013:..................................................................................4 • Integrated Resource Planning (IRP) – R.20-05-003; R.25-06-019:...........................................5 • Renewables Portfolio Standard (RPS) – R.24-01-017; CEC OIR 21-RPS-02:..............................7 • Resource Adequacy (RA) – R.23-10-011; R.25-10-003: ............................................................8 • Large Loads (PG&E Rule 30) – A.24-11-007:.............................................................................9 • Demand Response – R.25-09-004: .......................................................................................... 12 • PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast: ......................... 13 o 2024 ERRA Compliance – A.25-02-013: ............................................................................... 13 o 2025 ERRA Compliance – A.26-02-019 ................................................................................ 14 o 2026 ERRA Forecast – A.25-05-011:.................................................................................... 14 o 2027 ERRA Forecast – A.26-05-007:.................................................................................... 15 • PG&E General Rate Case (GRC) Phase 1 – A.25-05-009: ......................................................... 16 • PG&E General Rate Case Phase 2 – A.24-09-014: ................................................................... 17 • Provider of Last Resort (POLR) – R.21-03-011: ...................................................................... 19 • CEC Load Management Standards (LMS) – CEC 21-OIR-03; 26-OIR-01; 23-LMS-01:............... 20 • Power Charge Indifference Adjustment (PCIA) – R.25-02-005: .............................................. 21 • Safety & Reliability OIR– R.24-05-023: ................................................................................... 25 • Disconnections – R.18-07-005: ............................................................................................... 26 • High-DER Future – R.21-06-017:............................................................................................. 28 • Distributed Energy Resources – R.22-11-013: ........................................................................ 29 • Distributed Energy Resource Interconnections (Rule 21) – R.25-08-004:............................... 30 [Publish Date] Agenda Date: 9/17/2026

• BioMAT Implementation – R.18-07-003; R.22-10-010; R.24-01-017:
a. Proceeding Overview
i. Assembly Bill (AB) 843, chaptered in 2021, enabled CCAs to access the CPUC’s Bioenergy Market Adjusting Tariff (BioMAT) program, which is a feed-in-tariff program for small-scale bioenergy projects. The implementation of AB 843 was considered in R.22-10-010, while the ongoing review and revision of the BioMAT program continues to be considered in the RPS proceedings, R.18-07-003 and R.24- 01-017.
b. Potential Impact on Pioneer
i. Pioneer is an administrator of the BioMAT program, which acts as a much-needed incentive for local bioenergy development. The regulatory implementation of the BioMAT program, specifically regarding extension of the December 31, 2025 sunset date and revisions to the pricing mechanism, affects Pioneer's ability to effectively administer the program.
c. Key Issues
i. Expeditiously implement AB 843 to allow CCA access to the BioMAT program for future subsidies for biomass procurement
ii. Advocate for ongoing CPUC review and revisions to the BioMAT program’s sunset date, to ensure CCAs will be able to continue effectively administering the program d. Status Update
i. The BioMAT program closed on the currently effective sunset date of December 31, 2025. The CPUC removed its proposed decision responding to Bioenergy Association of California’s (BAC’s) PfM requesting an extension of this sunset date from its January 15, 2026 voting meeting agenda, meaning the program has effectively ended without CPUC action.
ii. April 10, 2026 - The CPUC issued a new PD denying BAC’s PfM, requesting extension of the BioMAT program, which was originally filed in March 2025. The CPUC previously issued a PD in response to BAC’s PfM in September 2025, but the PD was ultimately withdrawn and never passed. The new PD does not address the substance of BAC’s PfM, nor address the comments that parties including the Joint CCAs filed in response, but instead primarily makes a procedural argument for why the PfM is denied.
iii. May 14, 2026 – The CPUC issued D. 26-05-008, denying BAC’s PfM requesting extension of the BioMAT program. The CPUC stated that based on procedural grounds, BAC’s PfM was not appropriately addressed within one year of the original decision, D.20-08-043, setting the BioMAT program sunset date. iv. May 26, 2026 – BAC filed an application for rehearing (AfR) of D. 26-05-008, stating that the CPUC’s procedural argument is legally erroneous. v. June 4, 2026 – Pioneer and Redwood Coast Energy Authority (RCEA), namely the “Joint CCAs” had an ex parte with Commissioners Harada and Reynolds’ offices to request for the issue of BioMAT extension to be considered in the current RPS rulemaking. Pioneer discussed our recent success in executing six BioMAT PPAs, demonstrating stakeholders’ continued interest in the BioMAT program and the need for the CPUC to consider reviving/ extending it.
vi. September 1, 2026 – Pioneer filed an application for compliance review of its administration of the BioMAT program. In the application and supporting testimony, [Publish Date] Agenda Date: 9/17/2026

Pioneer seeks to establish compliance with the CPUC’s prudent contract manager standard by describing how Pioneer deemed the six BioMAT program participation requests (PPRs) it received and power purchase agreements (PPAs) it executed eligible for the program.
e. Background Documents/ Key Decisions
i. D.20-08-04, Revising the BioMAT Program (August 27, 2020):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M346/K112/346112503.PD F
• Most notably extending the program end date to December 31, 2025 ii. D.23-11-084, Implementing AB 843 – Setting Rules to Enable CCAs to Participate in the BioMAT Program (November 30, 2023):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M521/K266/521266723.PD F
iii. BAC PfM to Modify D.20-08-043 (March 6, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M558/K427/558427287.PDF • BAC urges the CPUC to consider extension of BioMAT sunset date iv. PD Denying BAC PfM to Modify D.20-08-043 (September 18, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M580/K430/580430313.PDF • Ultimately withdrawn from the CPUC Voting Meeting agenda, and never passed v. Opening Comments of Joint CCAs (Pioneer and RCEA) on PD Allowing the BioMAT Program to Sunset (October 8, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M582/K487/582487980.PDF vi. D. 26-05-008 Denying BAC PfM to Modify D. 20-08-043 (May 14, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M606/K808/606808546.PD F
vii. BAC Application for Rehearing of D. 26-05-008 (May 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M607/K644/607644121.PDF f. Key Dates
i. None.
g. Pioneer Lead: Chau Pham
• California Climate Credit – R. 25-07-013:
a. Proceeding Overview
i. This proceeding aims to improve the California Climate Credit (CCC) as a tool for supporting ratepayer affordability. Currently, these credits are distributed by the IOUs and are funded by revenues from the state’s Cap-and-Invest (formerly known as Cap-and-Trade) program. The credits are delivered twice a year to electric customers, typically in April and October, and once a year to gas customers, typically in April.
b. Potential Impact on Pioneer
i. Although Pioneer does not directly distribute the CCC, its residential and qualifying small business electricity customers still qualify for the CCC. Therefore, it is [Publish Date] Agenda Date: 9/17/2026

important to keep apprised of changes to the CCC, to ensure any changes are fair and beneficial for all ratepayers.
c. Key Issues
i. Ensure modifications to the CCC are competitively neutral, including eligibility criteria and customer messaging
ii. Ensure existing customers continue receiving the Climate Credit d. Status Update
i. February 3, 2026 – A Scoping Memo and Ruling was issued that outlined a phased approach for this proceeding including, Phase 1A which contemplates immediate changes to the CCC, Phase 1B which addresses broader changes, and Phase 2 which will later address the California Air Resources Board (CARB)’s new regulations for the Cap-and-Invest program that funds the CCC.
ii. March 19, 2026 – D. 26-03-013 was adopted, ordering the large electric IOUs to pause distribution of the 2026 residential climate credit, so the Commission can consider when the credits should be distributed.
iii. April 30, 2026 – D. 26-04-036 was adopted, requiring the large electric utilities to distribute the residential electric climate credits in August and September starting in 2026, and the gas utilities to distribute the residential gas climate credits in February starting in 2027. The rationale for shifting the distribution timeline of the climate credits is to move it to the highest-bill months, typically occurring in summer, where the credits can have a greater impact on alleviating costs. e. Background Documents/ Key Decisions
i. Scoping Ruling (February 3, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M597/K166/597166396.PDF ii. Decision Pausing the 2026 Residential Climate Credits Distributed by the Large Electric Utilities (March 19, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M603/K306/603306591.PD F
iii. Decision Ordering Immediate Improvements to the CCC to Lower Electric and Gas Bills (May 1, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M605/K990/605990203.PD F
f. Key Dates
i. None.
g. Pioneer Lead: Chau Pham
• Integrated Resource Planning (IRP) – R.20-05-003; R.25-06-019:
a. Proceeding Overview
i. This proceeding acts as the venue for long-term procurement planning, primarily through procurement mandates and compliance evaluations of LSEs' individual IRP plans. Historically, the CPUC has issued procurement mandates, most notably the mid-term reliability (MTR) orders, specifying how much and what kind of resources LSEs are obligated to buy, to ensure the state's electricity supply is reliable, cost-effective, and on track to meet greenhouse gas (GHG) reduction goals. The CPUC is [Publish Date] Agenda Date: 9/17/2026

currently developing a 10-year forward procurement program to support longer-term market stability, grid reliability, and GHG reduction goals. b. Potential Impact on Pioneer
i. Pioneer is required to comply with IRP procurement and filing requirements. IRP plans are due in 2-year cycles; the current cycle is 2024-2026; the next IRP plan will be due on May 5, 2026. Furthermore, CPUC-issued procurement orders have a significant impact on the procurement market that Pioneer operates in. Therefore, it is in Pioneer’s best interest to advocate for policies that ensure any CPUC-issued procurement orders preserve CCA procurement autonomy and flexibility to the highest degree possible, to ensure Pioneer can engage in fair, competitive, and cost-effective procurement. c. Key Issues
i. Minimize costly procurement orders coming from the IRP, especially near-term ad-hoc orders ii. Advocate for procurement planning policies that prioritize affordable baseload resources such as biomass energy
d. Status Update
i. June 23, 2026 – The CPUC issued a new Reliable and Clean Procurement Program (RCPPP) proposal (Option 3), to be considered in addition to the previous two proposals that were issued in April 2025. Given the wide variety of comments received on the RCPPP proposals in 2025 which show parties have not been able to reach consensus on a RCPPP framework, the CPUC proposes a simpler RCPPP framework in this new ruling. This RCPPP proposal intends to keep the IRP/ RCPPP program distinct from the RA program, by continuing to use different capacity valuation methodologies for the respective programs. The primary purpose of this RCPPP proposal is to connect long-term transmission planning with procurement orders. Under the proposed framework, the adoption of transmission planning process (TPP) portfolios would form the procurement needs for 5 years out, with a requirement of 100% of an LSEs’ resource obligation being contracted in year 3 and 100% of the resources being online in year 5. LSEs’ procurement obligations would be based on their peak system load share, as indicated in the CEC Integrated Energy Policy Report (IEPR), with an additional 1% buffer on top to account for uncertainties and delays. The proposed program would begin in 2028 with the adoption of the TPP portfolio and procurement need for 2033, recurring in 2-year TPP cycles. In many ways, this proposal retains a similar structure to the previous mid-term reliability procurement orders that have come out of the IRP proceeding but with a more regular cadence/ timeline, whereas the previous two RCPPP proposals issued in 2025 contained more sweeping changes and reform to align the IRP, RA, and RPS program. Pioneer will work with CalCCA to provide comments on the new proposal. The CPUC has indicated the next step in the development of the RCPPP framework is a PD.
ii. August 14, 2026 - CalCCA and 40+ parties filed comments on the RCPPP Option 3 proposal. CalCCA urged the CPUC to reject the RCPPP Option 3 proposal because tying procurement requirements to TPP portfolios would likely risk distorting the market, shifting power to sellers, and increasing ratepayer costs. Instead, CalCCA recommended the CPUC adopt the RCPPP Option 1 proposal which allows for procurement of new and existing resources, coupled with a Clean Energy Standard (CES) framework that ensures sufficient procurement of clean resources. If the CPUC insists on adopting a RCPPP framework that only allows for procurement of [Publish Date] Agenda Date: 9/17/2026

new resources, CalCCA recommended they adopt Option 2 with modifications to the need determination and need allocation methodologies, and compliance and enforcement components, to ensure proper flexibility.
iii. September 2, 2026 - CalCCA filed reply comments on the RCPPP Option 3 proposal.

CalCCA aligned with CAISO, SCE, CalAdvocates, and AReM on why Option 3 should be rejected, as parties find the framework to be too prescriptive, not reflective of market conditions, not aligned with the RA and RPS programs, and lacking pathways for procurement of long-lead time resources. CalCCA also urged the CPUC to reject party recommendations for prescriptive resource or attribute-specific procurement requirements, use of a central procurement entity, or a buffer. e. Background Documents/ Key Decisions
i. ALJ Ruling Seeking Comments on Reliable and Clean Power Procurement Program (RCPPP) Staff Proposal (April 29, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M565/K140/565140721.PDF ii. ALJ Ruling Seeking Comments on Proposed 2026-2027 Transmission Planning Process (TPP) Portfolios and Need for Additional Near-Term Reliability Procurement (September 30, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M582/K082/582082526.PDF iii. R.25-06-019 Scoping Memo and Ruling (October 28, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M585/K485/585485746.PDF iv. Proposed Decision Requiring 2029-2032 Electric Resource Procurement and Transmitting 2026-2027 Transmission Planning Process (TPP) Portfolios (January 14, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M595/K083/595083681.PDF v. ALJ Ruling Setting New Requirements for Individual Integrated Resource Plans Due June 1, 2026 (January 16, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M595/K085/595085015.PDF vi. Revised Decision Requiring 2029-2032 Electric Resource Procurement and Transmitting 2026-2027 TPP Portfolios (February 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M600/K398/600398976.PD F
vii. ALJ Ruling Granting Joint Request for Extension of LSEs’ IRP Filings (March 9, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M601/K895/601895997.PDF viii. ALJ Ruling Seeking Comments on Additional Proposal for RCPPP (June 23, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M609/K223/609223925.PDF f. Key Dates
g. Pioneer Lead: Chau Pham
• Renewables Portfolio Standard (RPS) – R.24-01-017; CEC OIR 21-RPS-02:
a. Proceeding Overview
i. This proceeding acts as the venue for the CPUC’s implementation and administration of the state's RPS program, which aims to achieve 60% renewable energy by 2030, and 100% carbon-free by 2045.
b. Potential Impact on Pioneer
[Publish Date] Agenda Date: 9/17/2026

i. Pioneer is required to comply with the state’s RPS goals. All retail sellers must submit an annual preliminary RPS compliance report each year on August 1, to be evaluated by the CPUC in this proceeding. RPS compliance is evaluated in multi-year periods; we are currently in compliance period 5 (2025-2027). The next RPS target is 52% by 2027. It is Pioneer's priority to ensure RPS rules maintain the highest compliance flexibility possible (allowing for banked RECs, etc) to allow for cost-effective procurement. c. Key Issues
i. Ensure any RPS rules maintain compliance flexibility to the highest degree possible ii. Advocate for fair inclusion of biomass resources in the RPS program and guidelines (this may also take place in the CEC RPS proceeding), including the ongoing administration of the BioMAT program
d. Status Update
i. March 27, 2026 - An ALJ ruling was issued identifying issues and schedule of review for 2026 RPS Procurement Plans. Minor revisions were made to the RPS Plan requirements. The annual draft RPS Plan will be due June 12, 2026. ii. May 7, 2025 - The CPUC approved Pioneer's Final 2025 RPS Procurement Plan. iii. August 21, 2026 – Pioneer filed its Final Compliance Period 4 (2021-2024) Compliance Report, providing data that showed Pioneer had fulfilled its RPS requirements for Period 4.
e. Background Documents/ Key Decisions
i. Pioneer Community Energy Draft 2025 RPS Procurement Plan (June 30, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M571/K990/571990166.PDF ii. PD on 2025 RPS Procurement Plans (November 14, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M587/K328/587328286.PDF iii. Pioneer Community Energy Final 2025 RPS Procurement Plan (January 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M596/K418/596418446.PDF f. Key Dates
g. Pioneer Lead: Chau Pham
• Resource Adequacy (RA) – R.23-10-011; R.25-10-003:
a. Proceeding Overview
i. This proceeding aims to ensure the reliability of CA's electricity supply by requiring that LSEs procure sufficient resources to meet their load plus a planning reserve margin (PRM). The RA program recently implemented a slice of day (SOD) framework, ensuring LSEs are compliant every hour of the worst day of the month. b. Potential Impact on Pioneer
i. Pioneer is required to comply with RA procurement requirements and filings. Annual (year ahead) filings are due on October 31 each year and monthly (month ahead) filings are due 45 calendar days prior to the compliance month. Furthermore, RA requirements have significant impacts on the procurement market which Pioneer operates in. Therefore, Pioneer advocates for RA procurement requirements and policies that minimize adverse effects on the RA market. [Publish Date] Agenda Date: 9/17/2026

c. Key Issues
i. Advocate for refinements in the RA program that minimize RA requirements (based on robust modeling) to ensure adequate market availability and guard against RA price volatility
ii. Advocate for simplifying RA showings/ compliance requirements to the greatest extent possible
d. Status Update
i. August 25, 2026 – An amended Scoping Ruling was issued to set the topics and schedule for Track 2, which includes:
• Adoption of 2028-2030 local and flexible capacity requirements • Planning reserve margin (PRM) for 2028-2029
• Unforced capacity (UCAP) implementation
• Accreditation of long duration energy storage (LDES) open-loop pumped storage hydropower (PSH), solar, wind, and non-dispatchable resources • Value of energy only (EO) resources towards charging sufficiency • RA penalty structure
e. Background Documents/ Key Decisions
i. Issuance of OIR 25-10-003 (October 15, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M583/K934/583934825.PD F
ii. Scoping Ruling (December 12, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M590/K884/590884355.PDF iii. ALJ Ruling on ED’s Transactability Report (February 23, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=600063407 iv. Revised Track 1 PD (June 30, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?docformat=ALL&docid=609912508 f. Key Dates
i. Fall 2026 – Issuance of Track 2 Scoping Memo and Schedule ii. Fall 2026 – Consideration of LOLE Studies and PRM Proposals iii. Winter 2027 – Consideration of Other Track 2 Proposals iv. Summer 2027 – Proposed Decision on Track 2
g. Pioneer Lead: Chau Pham
• Large Loads (PG&E Rule 30) – A.24-11-007:
a. Proceeding Overview
i. This is PG&E's proposed tariff to address the interconnection of non-residential customers requesting retail electric service at transmission-level voltages between 50 kilovolts (kV) and 230 kV, otherwise known as transmission-level customers.

These large loads are becoming more significant as data centers propagate. PG&E’s current electric rules are intended for distribution-level interconnections. As such, when a customer applies for transmission-level retail electric service, PG&E and the customer negotiate unique interconnection terms, and PG&E is required to make an “exceptional case” filing with the Commission for approval of the negotiated agreement. PG&E states that creating a uniform tariff (proposed Electric Rule 30) [Publish Date] Agenda Date: 9/17/2026

will streamline both the negotiation process and the approval process, resulting in faster interconnection timeline.
b. Potential Impact on Pioneer
i. New large loads, such as data centers, located in Pioneer’s service territory present both challenges and opportunities to Pioneer. If Pioneer is going to provide generation service to these customers, it needs visibility into which applications are expected to come online in its service territory (if any) for procurement planning purposes. It will also need to have a commitment from these customers far enough in advance for Pioneer to procure adequate resources to meet any compliance deadlines for serving these new loads.
c. Key Issues
i. Ensure Pioneer obtains information regarding new large loads when that information is obtained by the IOU, either before or at the time of a customer request for interconnection with the IOU’s transmission or distribution system; ii. Ensure the ability of Pioneer to adequately prepare to serve customers through timely access to information regarding large loads; and iii. Support customer choice of generation providers through ensuring IOUs and CCAs compete on a level playing field.
d. Status Update
i. May 8, 2026 – PG&E requested CPUC approval of a partial settlement agreement between itself, CalCCA, CalAdvocates, and Sierra Club. The relevant terms of the settlement agreement are as follows:
• Information Sharing (Under New NDA)
a. Interconnection Inquiries:
i. PG&E shall share the same information regarding all
transmission-level retail interconnection inquiries that it includes in submissions provided to the CEC at or about the same time that it provides this information to the CEC
b. Post-Application and Pre-Energization
i. Quarterly Reports regarding retail electric customers seeking to interconnect that have submitted an application for
transmission-level service
c. Post Energization
i. Annual Reports regarding facilities that have been
interconnected at the transmission-level and have been
energized
• Non-Disclosure Agreement
a. For affected CCAs, each CCA will execute a new NDA which will govern information sharing regarding interconnections for transmission level retail electric service under Electric Rule 30 or any other PG&E tariff rule
• Coordination of Service
[Publish Date] Agenda Date: 9/17/2026

a. CCAs are the default providers of generation service for new customers in their service areas
b. Customers will be considered enrolled with the default provider upon the customer’s execution of an interconnection agreement or eight months prior to the energization date identified in the Preliminary Engineering Study (PES) Report for the customer’s facility, whichever is earlier.
i. PG&E will provide an affected CCA notice of the energization date identified in the PES report within 3 business days of the customer’s signature of the PES report.
ii. PG&E will also provide an affected CCA notice of the execution of an interconnection agreement within 3 business days
c. Under California Public Utilities Code Section 366.2(c)(13), a transmission-level customer has a statutory 60-day opt out period after enrollment to opt out of default CCA generation service. d. Within 3 business days following the 60-day opt out period, the entity selected as the service provider shall confirm that it will provide generation service to the customer in writing to the other entity that will not be providing generation service to that customer. e. After the opt-out period, the customer cannot switch providers until at least one year after energization and after giving 18 months’ notice. ii. August 7, 2026 – The CPUC issued a ruling requesting comments related to FERC’s show cause order to CAISO and the Participating Transmission Owners (PTOs) in order to develop the record of the proceeding. The show cause order, issued on June 18, 2026, asks CAISO and the PTOs to explain how their tariffs support interconnection of large loads, or alternatively, to propose changes. FERC’s order aims to advance the goals of the Secretary of Energy’s efforts to expedite the integration of large loads onto the transmission system. e. Background Documents/ Key Decisions
i. PG&E Application for Approval of Electric Rule No. 30 for Transmission-Level Retail Electric Service (Nov. 21, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=547155949 ii. Joint CCA Response to Application (Dec. 23, 2024):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M549/K797/549797836.PDF iii. PG&E Motion for Interim Implementation of Rule 30 (Jan. 24, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=555445559 iv. Joint CCA Response to Motion for Interim Implementation (Feb. 10, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=556602084 v. Scoping Ruling (March 11, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=558423070 vi. D.25-07-039, partly granting PG&E’s Motion for Interim Implementation of Rule 30 (July 28, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M574/K875/574875643.PD F
[Publish Date] Agenda Date: 9/17/2026

vii. Order Instituting Proceeding Under Section 206 of the Federal Power Act (June 18, 2026): https://www.ferc.gov/media/e-10-el26-71-000
f. Key Dates
i. March 13, 2026 – Limited Opening Testimony on additional cost allocation questions in a January 9, 2026 Ruling
ii. April 8, 2026 – Rebuttal Testimony on additional cost allocation questions iii. April 15, 2026 through April 17, 2026– Evidentiary Hearings iv. questions
v. May 8, 2026 – Opening Briefs on additional cost allocation questions vi. May 22, 2026 - Reply Briefs on all issues
vii. Late July 2026 – Proposed Decision
viii. August/September 2026 – CPUC Decision
g. Pioneer Lead: Braden Henderson
• Demand Response – R.25-09-004:
a. Proceeding Overview
i. This rulemaking will revisit and enhance the CPUC's "demand response guiding principles, policies, and data system and process requirements." In particular, the rulemaking seeks to enhance the consistency, predictability, reliability, and cost-effectiveness of demand response (DR) resources. Issues that the CPCU could address in this proceeding are dual participation of DR resources among different programs, adjustments to the DR guiding principles, and integration into other systems and processes, including resource adequacy slice of day (RA SOD) and the CAISO market.
b. Potential Impact on Pioneer
i. Under the law, demand response and energy efficiency are the first resources that electric corporations use to meet their needs, so there is a statutory mandate to generally include it in the California resource mix. There could also be a specific impact on Pioneer's programs that fall under the umbrella of demand response, including the PowerShift Rewards program.
c. Key Issues
i. Pursue systems and processes that support timely and consistent Pioneer access to customer interval data, both billing-quality and non-billing-quality ii. Ensure Pioneer customers have equitable access to demand response resources iii. Ensure new policies or programs do not encroach on Pioneer rate and program autonomy
d. Status Update
i. July 7, 2026 - ALJ ruled to eliminate the testimony, evidentiary hearing, and briefs from the schedule as no disputed material facts or questions of law, regarding the Bridge Year Funding Issue, emerged from the comment and reply comment periods.
e. Background Documents/ Key Decisions
[Publish Date] Agenda Date: 9/17/2026

i. Order Instituting Rulemaking (Sept. 18, 2025) (including the Demand Response Guiding Principles Staff Report):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M582/K072/582072320.PD F
ii. Scoping Memo and Ruling (Feb. 12, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=599038857 f. Key Dates
i. April 30, 2026 – Opening Comments on Bridge Funding Staff Proposal Ruling ii. May 21, 2026 – Reply Comments on Bridge Funding Staff Proposal Ruling iii. Q3 2026 – Proposed Decision on IOU DR Bridge Funding iv. Q4 2026 – Proposed Decision on all other issues
g. Pioneer Lead: Braden Henderson
• PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast:
a. Proceedings Overview
i. Generally, the ERRA Compliance proceedings review IOU accounting for its generation costs in the previous year, which includes accounting related to the Power Charge Indifference Adjustment (PCIA) and Portfolio Allocation Balancing Account (PABA). The purpose is to ensure accuracy and compliance with legal requirements, including CPUC rules and decisions.
b. Potential Impact on Pioneer
i. Although typically not as contentious as the ERRA Forecast proceedings, PG&E's applications in the ERRA Compliance proceedings often include errors or non-compliant activities which, when corrected, result in a credit to unbundled customers via the PCIA which is incorporated in the ERRA Forecast proceedings. This proceeding is also an opportunity to review PG&E's activities related to its PCIA resources, although transparency is always a challenge.
ii. This is the proceeding in which the PCIA revenue requirement for the following rate year (i.e., 2026 in this proceeding) is established. Parties and the CPUC arrive at the revenue requirement by reducing the costs of the PCIA resources by their value and adding any over or under-collection of the PCIA from the current rate year (i.e., 2025 in this proceeding). That revenue requirement is then assigned to customer vintages depending on the vintage of the resource to develop PCIA rates. Given all of Pioneer's customers pay PCIA rates, Pioneer's goal is to ensure that its customers are only paying the costs that we actually incurred on their behalf and receiving the full value of the PCIA resources.
o 2024 ERRA Compliance – A.25-02-013:
a. Key Pioneer Issues
i. Ensure qualifying facilities and contracts were prudently administered and managed, entries in balancing and memorandum accounts were recorded appropriately, correctly, and in compliance with CPUC decisions, and whether recovery for 2024 record year costs is reasonable.
b. Status Update
i. No updates.
[Publish Date] Agenda Date: 9/17/2026

c. Background Documents/ Key Decisions
i. PG&E Application (February 28, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=557607577 ii. CalCCA Protest (April 4, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=561478629 iii. Scoping Ruling (May 2, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=565140242 d. Key Dates
i. Intervenors' Testimony - September 15, 2025
ii. Rebuttal Testimony - October 24, 2025
iii. Evidentiary Hearing - December 2, 2025
iv. Opening Briefs - January 5, 2026
v. Reply Briefs - February 6, 2026
vi. Proposed Decision - no later than 90 days after reply briefs vii. Final Decision - no sooner than 30 days after Proposed Decision e. Pioneer Lead: Chau Pham
o 2025 ERRA Compliance – A.26-02-019
a. Key Pioneer Issues
i. Ensure qualifying facilities and contracts were prudently administered and managed, entries in balancing and memorandum accounts were recorded appropriately, correctly, and in compliance with CPUC decisions, and whether recovery for 2024 record year costs is reasonable.
b. Status Update
i. CalCCA reviewed PG&E’s ERRA filing and had only minor changes that PG&E has agreed to make. CalCCA therefore will not request testimony on any issues. c. Background Documents/ Key Decisions
i. PG&E Application (February 27, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M601/K158/601158608.PDF ii. CalCCA Protest (April 2, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M604/K016/604016143.PDF d. Key Dates
e. Pioneer Lead: Jon Hart
o 2026 ERRA Forecast – A.25-05-011:
a. Key Pioneer Issues
i. Ensure accuracy of forecast account balances and rates, cost calculations in workpapers, and calculation of Market Price Benchmarks (MPBs) ii. Ensure costs are attributed to the proper PCIA vintage iii. Ensure costs are attributed properly between bundled and unbundled customers iv. Ensure IOU specific proposals are appropriate for an ERRA Forecast proceeding [Publish Date] Agenda Date: 9/17/2026

b. Status Update
i. No updates.
c. Background Documents/ Key Decisions
i. PG&E Application (May 15, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566243428 ii. Scoping Ruling (June 20, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=574962660 iii. CalCCA Brief (October 24, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=585485747 d. Key Dates
i. A final decision in this proceeding is anticipated in December 2025, with implementation into rates beginning January 1, 2026.
e. Pioneer Lead: Chau Pham
o 2027 ERRA Forecast – A.26-05-007:
a. Key Pioneer Issues
i. Ensure accuracy of forecast account balances and rates, cost calculations in workpapers, and calculation of Market Price Benchmarks (MPBs) ii. Ensure costs are attributed to the proper PCIA vintage iii. Ensure costs are attributed properly between bundled and unbundled customers iv. Ensure IOU specific proposals are appropriate for an ERRA Forecast proceeding b. Status Update
i. May 15, 2026 - PG&E filed its 2027 ERRA Forecast application. The initial application forecasts that PCIA rates for unbundled customers are going to decrease, but that rate is expected to increase from now until the October update and annual true-up due to PG&E using outdated values (2026 GRC revenue requirement, 2026 RA/ RPS MPBs).

The application projects a 1.7 c/kWh (7.3% decrease over present system average rates) for CCA/DA customers and an increase of 1.9 c/kWh (5.7% increase over present system) for bundled customers. NewGen found that the biggest driver in downward pressure on the PCIA and upward pressure on generation rates is the change in PG&E's balancing accounts from 2025 to 2026, which are overshadowing the low energy prices.
ii. August 3, 2026 – The CPUC issued a Scoping Memo with dates for all forthcoming filings and expected date for a final decision (December 17, 2026). iii. August 27, 2026 – CalCCA filed testimony on PG&E’s 2027 ERRA Forecast application.

The testimony requests that PG&E revise its implementation of slice-of-day accounting as part of resource adequacy; PG&E value pre-2019 banked RECs; and that PG&E provide accurate forecasting for data centers. Currently, PG&E is forecasting large amounts of data centers coming online which would drive up PCIA rates. It is unlikely that all of this load will materialize, so we want the forecast to be as accurate as possible so our PCIA rates are not impacted.
c. Background Documents/ Key Decisions
i. PG&E Application (May 15, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566243428 [Publish Date] Agenda Date: 9/17/2026

d. Key Dates
i. September 16, 2026 – PG&E Rebuttal Testimony Due
ii. October 16, 2026 – PG&E update to forecast
iii. November 2026 – Proposed Decision
iv. December 17, 2026 – Final Decision
e. Pioneer Lead: Jon Hart
• PG&E General Rate Case (GRC) Phase 1 – A.25-05-009:
a. Proceeding Overview
i. In four-year cycles, IOUs submit GRC applications for authority to adjust rates and charges for electric and gas service based on a future test year (TY). The revenue requirements include electric and gas distribution system costs, administrative expenses, and customer service costs.
ii. In the GRC Phase 1, the CPUC establishes the IOU's overall revenue requirement, which is later allocated in rates to different customer classes in the GRC Phase 2.

This includes establishing the operating and capital costs to be recovered for the IOU's transmission, distribution, and generation functions. b. Potential Impact on Pioneer
i. The costs of PG&E's Power Charge Indifference Adjustment (PCIA) generation resources will be established here and later recovered through the PCIA rates via the ERRA Forecast proceeding.
ii. This proceeding will also establish revenue requirements for PG&E programs that could benefit customers in Pioneer's service territory, including resiliency and backup power initiatives to support areas disproportionately impacted by outages. c. Key Issues
i. Ensure accuracy and reasonableness of forecast costs ii. Ensure revenue requirements are properly allocated to PCIA vintages iii. Ensure costs are properly allocated across major work categories iv. Prevent unwarranted or unreasonable increases to CCA service fees d. Status Update
i. February 13, 2026 – CalCCA filed testimony on PG&E’s application proposing the various changes that would lower the generation revenue collected through the PCIA, including, but not limited to:
• Removing hydro facilities that erroneously remain on PG&E’s books and those that are no longer used and useful in providing generation services for the benefit of customers from the Electric Generation revenue requirement while recovering any remaining balance of the original investment through a regulatory asset, with no return on rate base and
• Moving eight hydro facilities into a more recent vintage for the purposes of PCIA cost recovery to reflect the fact that the substantial proposed investments in these assets of over $2 billion would result in a significant [Publish Date] Agenda Date: 9/17/2026

overhaul of these facilities, supporting life extensions as well as changed functions for these assets.
ii. April 27 – May 6, 2026 – CalCCA is participating in Evidentiary Hearings. CalCCA’s witness Ryan Matley is scheduled to be cross-examined on May 13, 2026. CalCCA’s cross-examination of PG&E’s witnesses will focus on hydro facility costs, proposed investments, and the correct vintaging of those hydro investments. PG&E has hydro assets that are on the books but have not been used, as well as new investments that may require re-vintaging.
e. Background Documents/ Key Decisions
i. PG&E Phase 1 2027 Application (May 15, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566363587 ii. PG&E Phase 1 2027 Scoping Ruling (July 31, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=575112973 f. Key Dates
i. Intervenors’ testimony - February 13, 2026
ii. Rebuttal testimony - March 31, 2026
iii. Case Management Conference
iv. Statement and Motions for Settlement - April 13, 2026 v. Evidentiary hearings - Starting April 27, 2026
vi. Opening briefs - June 19, 2026
vii. Reply briefs - July 10, 2026
viii. Proposed decision - March 2027
ix. Commission decision May - 2027
g. Pioneer Lead: Jon Hart
• PG&E General Rate Case Phase 2 – A.24-09-014:
a. Proceeding Overview
i. In four-year cycles, IOUs submit GRC applications for authority to adjust rates and charges for electric and gas service based on a future test year (TY). The revenue requirements include electric and gas distribution system costs, administrative expenses, and customer service costs
ii. The GRC Phase 2 is focused on the design of PG&E's rates, and includes proposals for real-time pricing rates. This follows the GRC Phase 1, which determines the cost of service.
b. Potential Impact on Pioneer
i. PG&E is proposing to escalate fees for meter data management, rate ready consolidated billing fee, and bill-ready consolidated billing fee. ii. How PG&E implements RTP and how pricing and usage data is transferred to CCAs will impact CCAs' ability to implement their own dynamic pricing programs and potential implicate their compliance with the load management standards (LMS) of the California Energy Commission (CEC).
[Publish Date] Agenda Date: 9/17/2026

iii. PG&E's real-time pricing (RTP) proposal would include hourly components for each of transmission, distribution, and generation. For unbundled customers, CCAs will have the option to customize the MEC and MGCC formulas or apply a modifier. PG&E says it is working with CCAs to provide options to develop more customized dynamic generation rates; however, such customizations will need to be funded by the CCAs.

If CCAs want to use a different generation marginal RTP, they may contract with another entity to develop that price and calculate their unbundled customers’ generation bill.
c. Key Issues
i. Ensure that CCAs have access to data needed to implement dynamic rates for any CCA that chooses to do so and ensure that PG&E's implementation of dynamic rates does that impede CCA ability to comply with CEC LMS rules. d. Status Update
i. March 9, 2026 – CalCCA submitted testimony recommending that the CPUC:
• Reject PG&E’s proposed 20 percent increases to its CCA Service Fees; • Order PG&E to complete a cost study to support any future recommended changes to its CCA Service Fees;
• Order PG&E to: (1) cap its revenues associated with the CCA Service Fees at the cost levels included in its forecast for these services provided in its 2027 Phase I General Rate Case (GRC) Application (A.) 25-05-009; and (2) track any revenue received above that cap and refund this amount to unbundled customers via PG&E’s next Energy Resource Recovery Account (ERRA) compliance proceeding;
• Reject PG&E’s proposal to update its CCA Service Fees via Tier 2 Advice Letters in the future, and instead reiterate that PG&E may only update these fees via a GRC application, and that any such update must be supported by up-to-date information regarding PG&E’s actual costs incurred in the provision of these services; and
• Order PG&E to update its Provider of Last Resort (POLR) fee for CCA customers by: (1) submitting supplemental testimony in this proceeding regarding its actual costs as the POLR to process a customer’s voluntary return to bundled service in 2026, using up-to-date data on PG&E’s processing times and labor costs; and (2) shortly after PG&E’s final implementation of its Billing Modernization Initiative (BMI) project, submitting testimony in its next GRC application regarding its actual costs as the POLR to process a customer’s voluntary return to bundled service, using up-to-date data on PG&E’s processing times and labor costs
e. Background Documents/ Key Decisions
i. PG&E Phase 2 2023 Application (Sept. 30, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=541493803 ii. PG&E Phase 2 2023 Scoping Ruling (Mar. 21, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=560273042 f. Key Dates
i. Cal Advocates Testimony -January 9, 2026
ii. Intervenors' Testimony – March 9, 2026
[Publish Date] Agenda Date: 9/17/2026

iii. Rebuttal Testimony – July 10, 2026
iv. Hearing - August 2026
v. Opening Briefs - Four weeks after Hearing
vi. Reply Briefs - Three weeks after Opening Briefs
vii. Proposed Decision - No later than 90 days after Reply Briefs viii. Final Decision - No sooner than 30 days after Proposed Decision g. Pioneer Lead: Jon Hart
• Provider of Last Resort (POLR) – R.21-03-011:
a. Proceeding Overview
i. Track 1 of the POLR proceeding serves to determine/ update the methodology for the financial security requirement (FSR) that CCAs have to post, to ensure the IOUs (Current POLRs) have the capital to serve customers in case of an emergency mass return. Track 2 of the proceeding gauged interest from any LSEs/ IOUs who are interested in taking on the role of POLR.
b. Potential Impact on Pioneer
i. Pioneer would like to minimize changes to the FSR methodology that could increase it. It's also important to stay up to date with any changes in the process/ timing of posting Pioneer’s FSR.
c. Key Issues
i. Prevent the requirement for the POLR to procure or hedge in advance of customer return
ii. Ensure modifications to the FSR are balanced and improve accuracy iii. Adjust the FSR calculation to account for risk of customer return through an unsecured credit limit
iv. Reject the adoption of PG&E’s outsized “liquidity pool” that would remove the revenue offset component of the calculation entirely
v. Ensure non-IOU LSEs are able to serve as POLR under similar rules as the IOU as POLR
d. Status Update
i. No updates.
e. Background Documents/ Key Decisions
i. Scoping Ruling (Sept. 16, 2021):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M407/K765/407765425.PDF ii. CalCCA Comments (July 5, 2022) on Ruling Requesting Comments on the FSR and Re-Entry Fee (May 2, 2022):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=490740399 iii. ED Staff Proposal (Jan. 6, 2023):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M500/K762/500762116.PDF iv. D.24-04-009 (Apr. 18, 2024) Decision Implementing SB 520 Regarding Standards for POLR:
[Publish Date] Agenda Date: 9/17/2026

https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M529/K986/529986322.PD F
v. Phase 2 Scoping Ruling (Oct. 24, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=543727359 f. Key Dates
i. Track 2 of POLR is on pause, due to lack of substantial interest from LSEs in transferring POLR role.
g. Pioneer Lead: Chau Pham
• CEC Load Management Standards (LMS) – CEC 21-OIR-03; 26-OIR-01; 23-LMS-01:
a. Proceeding Overview
i. Docket 23-LMS-01 implements the CEC’s LMS (Calif. Code of Regulations, Title 20, sections 1621-1625), which include (among other mandates) requirements for CCAs to develop dynamic pricing by 2027. The objective of the LMS is to increase statewide demand flexibility through the development of hourly locational marginal cost-based rates. The rates will be entered into a statewide database – the MIDAS – and automation service providers will access customers’ rate information through a “Single Statewide Tool” created jointly by the IOUs, CCAs, and POUs. The statewide system of granular time and location dependent signals are intended to be used by automation-enabled loads to provide real-time load flexibility on the electric grid.

The CEC adopted the LMS Regulations on October 12, 2022, in docket 21-OIR-03. b. Potential Impact on Pioneer
i. The LMS rules include compliance obligations for large CCAs, like Pioneer. These compliance obligations include submission of an LMS plan and to consider adopting real-time rates. Although Pioneer's public position is that the CEC does not have authority over CCA rates, Pioneer will continue to make all reasonable efforts to comply with LMS as a show of good faith cooperation with California policies regarding dynamic rates.
c. Key Issues
i. Ensure implementation of the LMS regulations is fair and equitable to CCAs, and ii. in accordance with the regulations
iii. Ensure that the CEC respects CCA autonomy in setting their own rates iv. Ensure Pioneer maintains compliance with CEC mandates and requirements d. Status Update
i. April 9, 2026 – The CEC issued an Order Instituting Rulemaking to evaluate improvements to implementation of the LMS and expand participation among ratepayers and third-party service providers.
e. Background Documents/ Key Decisions
i. Load Management Standards: https://www.energy.ca.gov/programs-and-topics/topics/load-flexibility/load-management-standards ii. Pioneer Revised Load Management Standard Plan:
https://efiling.energy.ca.gov/GetDocument.aspx?tn=266073&DocumentContentId= 103090
[Publish Date] Agenda Date: 9/17/2026

f. Key Dates
i. July 1, 2025: Submit at least one marginal cost-based rate or program to the Pioneer Board for approval for any customer class where such a rate will materially reduce peak load.
ii. December 8, 2025: Pioneer's Revised LMS Plan will be addressed in the Energy Commission's Business Meeting.
iii. May 8, 2026: Develop and submit to the CEC, in conjunction with the other obligated utilities, a single statewide standard tool for authorized rate data access by third parties along with the terms and conditions for use of the tool. Upon CEC approval, the tool will be live and obligated LSEs must maintain and improve the tool iv. One year after compliance plan approval (December 8, 2026) and annual thereafter:

Submit annual reports to CEC demonstrating implementation of the Plan, as approved by the Board.
v. July 1, 2027: Offer each Pioneer customer voluntary participation in either a marginal cost-based rate, if such rate is approved by Pioneer’s Board, or a cost-effective load flexibility program identified in 20 CCR section 1623.1(b)(3). vi. Three years after compliance plan approval (December 8, 2028) and triennially thereafter: Review the Plan at least once every 3 years after the Plan is adopted by the Pioneer board. Submit any updates of the Plan to the Board if there is a material change.
g. Pioneer Lead: Braden Henderson
• Power Charge Indifference Adjustment (PCIA) – R.25-02-005:
a. Proceeding Overview
i. This proceeding will consider the rules and processes related to the Energy Resource Recovery Account (ERRA) and PCIA, which are the mechanisms by which unbundled customers are assessed the costs for generation resources procured by the IOUs on their behalf. The Commission bifurcated the proceeding into two tracks - Track One is an expedited consideration of modifications to the market price benchmark (MPB) calculations and Track Two will be a more holistic review of potential changes to the ERRA and PCIA, potentially including, for example, sunsetting or re-vintaging resources, changes to Bundled Procurement Plans (BPPs), and incorporation of slice of day.
b. Potential Impact on Pioneer
i. In the recent ERRA forecast cases, the PCIA has been negative for certain vintages of unbundled customers, meaning they will see a credit on their bill for the value of IOU resources procured on their behalf. This has drawn the scrutiny of the IOUs, ratepayer advocates, and the CPUC, resulting in a reassessment of certain components of the PCIA calculation, particularly the RA MPB, which, given current high RA prices, has contributed to the negative PCIA. Changes to the Market Price Benchmarks (MPBs), and PCIA methodology in general, could result in shifting costs for IOU generation resources from bundled to unbundled customers. On the flipside, the wholistic nature of Track 2 provides an opportunity to fundamental revisit the PCIA structure and propose solutions to help limit exposure for CCAs and prevent unfair cost shifts between bundled and unbundled customers. c. Key Issues
[Publish Date] Agenda Date: 9/17/2026

i. Track 1
• Revisions to the RA MPB, which is an element of the value attributed to PCIA resources.
ii. Track 2
• How to value renewable energy certificates (REC) generated prior to January 1, 2019, and used for bundled service customer compliance, for the purpose of calculating the PCIA (Pre-2019 Banked RECs)
iii. Track 3
• 3a: Revisions to vintaging of generators and the MPB for RPS, Energy Only, and GHG-Free resources
• 3b: Structural changes to the PCIA to make it more accurate d. Status Update
i. December 1, 2025 - the California Community Choice Association (CalCCA) filed a Writ of Review (Writ) appealing a decision by the California Public Utilities Commission (CPUC) that will result in a shift of hundreds of millions of dollars from unbundled to bundled customers via the Power Charge Indifference Adjustment (PCIA). In its Writ, CalCCA explains that the CPUC’s arbitrary decision to change the PCIA methodology and apply that change 2025 rates violates the longstanding prohibition against retroactive ratemaking, which is intended to ensure customer certainty and stability in rates. Before the Court of Appeals determines whether to take up the appeal, the CPUC will have an opportunity to respond to the Writ and CalCCA will reply to the CPUC response.
ii. March 2, 2026 – CalCCA submitted testimony on the Pre-2019 Banked RECs issue which:
• Explains how the PCIA framework operates to ensure statutory indifference between bundled and unbundled customers, including how REC value is conveyed to customers;
• Demonstrates that Later Departing Customers paid for their share of Pre-2019 Banked RECs when those RECs were generated but have not received the value of those RECs when they are later used for Current Bundled Customer RPS compliance;
• Shows that failure to credit Later Departing Customers when Pre-2019 Banked RECs are used for Current Bundled Customer compliance results in a cost shift from Current Bundled Customers to Later Departing Customers; • Recommends that Pre-2019 Banked RECs be valued at the current RPS MPB – the avoided cost of procuring new RECs in the market – when used for Current Bundled Customer compliance, with the full value recorded as a vintage-specific credit to the PCIA corresponding to the year the RECs were generated; • Explains why vintage-specific crediting ensures only the correct customer vintages receive the correct values and prevents double compensation; • Concludes that CalCCA’s proposal is consistent with Commission precedent, maintains statutory indifference, and can be implemented within the existing PCIA framework; and that
• In the absence of valuation, the Commission is required pursuant to Public Utilities Code section 366.2(g) to provide an allocation to Later Departing Customers for their share of RECs used by the IOU of Pre-2019 Banked RECs, which could be achieved by reducing the Net RPS Procurement Need as [Publish Date] Agenda Date: 9/17/2026

measured on the Commission’s Renewable Net Short Calculation template for the LSEs serving those Later Departing Customers.
iii. A Ruling was issued March 27, 2026, with an Energy Division Staff Report presenting “alternative approaches” to the IOUs and CalCCA’s proposals for valuing Pre-2019 Banked RECs. Energy Division does propose valuing the RECs (as opposed to the IOUs proposal to value the Pre-2019 Banked RECs at zero). CalCCA is evaluating ED’s four proposed valuation methods for Pre-2019 Banked RECs: (1) Load-share weighted RPS MPB; (2) DOE statewide renewable energy contract value assigned in D.11-12-018; (3) Valuation of Pre-2019 Banked RECs at 50 percent of current RPS MPB; and (4) “adjusted weighted mechanism” to value the RECs commensurate to the departed load share. Comments on the Staff Report are due with the Track 2 Opening Briefs, due May 22, 2026.
iv. May 12, 2026 - CalCCA filed testimony on Energy Division’s (Staff) report evaluating the pre-2019 banked RECs issue, rejecting Staff’s proposals and continuing to advocate for the RECs to be valued at the RPS MPB. CalCCA reiterated this stance in its subsequent rebuttal testimony filed May 22, 2026. In the rebuttal testimony, CalCCA put forth an alternative proposal to use a compliance-tier-weighted-formula of 90% of the current year RPS MPB plus 10% of the PCC-3 market price. v. June 16, 2026 – In Track 2 of the PCIA proceeding, CalCCA filed its opening brief, asking the CPUC to value pre-2019 banked RECs at their compliance value through either 1) PCC-1 prices, 2) allocating the attributes, or 3) as an alternative to ED staff proposals, value the RECs at 90% RPS MPB and 10% PCC-3 price. CalCCA reiterated this stance in its reply brief, filed June 25, 2026.
vi. June 25, 2026 – CalCCA’s Petition for Writ of Review of the CPUC’s Track 1 PCIA decision applying the RA MPB changes retroactively to the 2025 true-up was summarily denied by the 3rd District Court of Appeals, with no substantive reasoning provided. Following this, CalCCA filed a Petition with the California Supreme Court on July 7, 2026, asking the higher court to uphold California’s prohibition on retroactive ratemaking.
vii. July 9, 2026 – CalCCA filed comments in response to an ALJ ruling seeking comments on Track 3 scope. CalCCA reiterated the stances it made throughout the CPUC workshops hosted on June 8, 9, and 15 regarding Track 3 scope. The workshops covered the topics of 1) structural changes to the PCIA, 2) refinements to the PCIA and ERRA methodologies, and 3) data access issues. CalCCA’s comments put forth its stance that Track 3 should be scoped broadly enough to enable consideration of a fair and long-term solution that will ensure indifference and rate stability for all ratepayers. The comments also recommended that the CPUC prioritize the issue of re-vintaging resources to ensure they do not stay in the PCIA portfolio indefinitely, modifying the RPS MPB to create more consistency with the newly adopted RA MPB methodology, and build in adequate time to evaluate data access proposals.
viii. August 13, 2026 – The CPUC issued a proposed decision on Track 2 that values pre-2019 banked RECs at $0 for CCA customers. This came as a surprise as Energy Division and the Public Advocates Office had proposed valuing these RECs. ix. August 31, 2026 – CalCCA gave oral arguments on the Track 2 proposed decision and requested that the Commission issue an alternate proposed decision that values the RECs at one of the proposed valuation methodologies from either CalCCA, Energy Division, or the Public Advocates Office.
[Publish Date] Agenda Date: 9/17/2026

x. August 18, 2026 – The CPUC issued a scoping memo for the remaining tracks in the proceeding. Track 3 was split into 2 tracks, 3a and 3b. 3a will focus on revisions to the MPB for RPS, Energy-Only, and GHG-free resources while 3b will look at making structural changes to the PCIA itself. There will also be a track 4 to address any other outstanding issues.
e. Background Documents/ Key Decisions
i. OIR to Update and Reform ERRA and PCIA Policies and Processes (Feb. 26, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=557860748 ii. Track 1 Scoping Ruling (Apr. 8, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=562084645 iii. D.25-06-049 adopted Track 1 RA MPB methodology changes (June 26, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=571242473 iv. Track 2 Scoping Ruling (Feb. 3, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M597/K166/597166403.PDF v. Track 2 Proposed Decision (Aug. 13, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M614/K474/614474061.PDF vi. Track 3 and 4 Scoping Memo (Aug. 18, 2026)
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M615/K003/615003279.PDF f. Key Dates
i. Track one is completed at the regulatory level but could be revisited depending on the outcome of the appeal brought by CalCCA.
ii. Track 2:
• May 12, 2026 – Testimony on Staff Report
• May 22, 2026 – Rebuttal Testimony on Staff Report
• May 26, 2026 – Deadline to Present Settlement on Track 2 Issues or a Motion to Request Hearings
• May 27, 2026 – ALJ Ruling on the Need for Hearing
• June 2, 2026 – Evidentiary Hearing, if needed
• June 16, 2026 – Track 2 Opening Briefs
• June 25, 2026 – Track 2 Reply Briefs
• By August 17, 2026 – Proposed Decision issues
• September 17, 2026 – CPUC Decision
iii. Track 3:
• 3a:
a. October 2026 – Joint Case Management Statement from IOUs and CalCCA
b. October 2026 – Staff report or proposal
c. December 2026 – Parties file proposals
d. Q1 2027 – Workshop on proposals
[Publish Date] Agenda Date: 9/17/2026

e. Q1 2027 – Party comments/reply comments on proposals f. Q1/Q2 2027 – Proposed Decision
• 3b:
a. A schedule will be issued in Q4 2026
iv. Track 4:
• TBD
g. Pioneer Lead: Jon Hart
• Safety & Reliability OIR– R.24-05-023:
a. Proceeding Overview
i. This is a multi-track rulemaking to consider changes to policies related to safety, reliability, and resiliency of electric distribution systems. The near-term focus of this proceeding will develop processes for how the investor-owned utilities will collect and aggregate data to establish a foundation for measuring utility outages. b. Potential Impact on Pioneer
i. This proceeding is closely related to Public Safety Power Shutoff (PSPS) and Enhanced Powerline Safety Setting (EPSS) events which are of critical concern to Pioneer and its customers. Pioneer is likely to support:
• Transparency on the cause of outages to customers.
• Alternative approaches to reduce EPSS and PSPS events. • Protecting customers from increased costs while increasing reliability. c. Key Issues
i. The focus of the Rulemaking is to evaluate the safety, reliability, and resiliency of the electric distribution system. A major component of the rulemaking are outage events. The IOU’s planned outages are from scheduled maintenance, PSPS, and rotating outages during heatwaves. The IOU’s unplanned outages occur due to damage to equipment, EPSS, and by first responder request. PSPS and EPSS events are of particular concern for vulnerable areas; PSPS events have seemingly reduced in recent years but have been replaced with EPSS events. Overall, total outages events have been increasing since 2015, while outage duration peaked in 2019, outages are now leveling out or trending downward.
d. Background Documents/ Key Decisions
i. R.18-12-005, OIR to Examine Electric Utility De-Energization of Power Lines in Dangerous Conditions, Scoping Ruling (Mar. 08, 2019):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M270/K419/270419337.PDF ii. R.18-04-019, OIR to Consider Strategies and Guidance for Climate Change Adaptation, Scoping Ruling (Oct. 10, 2018):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M231/K128/231128764.PDF iii. R. 21-06-017, OIR to Modernize the Electric Grid for a High Distributed Energy Resource Future, Scoping Ruling (Nov. 15, 2021):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M422/K949/422949772.PDF e. Status Update
[Publish Date] Agenda Date: 9/17/2026

i. December 15, 2025 - The three IOUs submitted a Draft Customer Reliability Report Template. The report proposes to submit annual reporting of safety and reliability metrics leveraging a narrative reporting format. The submission identifies new metrics to report but the draft likely requires additional clarification on terms and metrics. Pioneer's joint party to file reply comments requesting further clarification. ii. January 26, 2025 - Pioneer's joint party has filed reply comments requesting further clarification on the IOU’s proposed metrics. The party has advocated for the IOUs to provide meaningful analysis within future reports on how customers are being impacted by outages including PSPS and EPSS events.
iii. July 10, 2026 – The Commission issued a proposed decision to adopt the IOUs’ Customer Reliability Report Template with modifications. Pioneer’s joint party successfully advocated for separate reporting and evaluation of PSPS and EPSS events. Adoption of this proposed decision would close the proceeding. iv. July 30, 2026 - Pioneer's joint party submitted comments on the proposed decision.

The comments address the need to keep the proceeding open to address meaningful reforms to safety and reliability.
v. August 13, 2026 - The Commission adopted the proposed decision requiring the IOUs to submit an Annual Electric Reliability Report based on the Template & Customer Reliability Schema developed through this proceeding, due on August 15th of each year. The IOUs will be required to hold a stakeholder workshop within 90 days after the first outage reports are submitted in 2027. The outage reporting requirement and Annual Electric Reliability Report will have a sunset date of August 2036. This proceeding is now closed.
f. Key Dates
i. Proposed Decision – July 10, 2026
ii. Final Decision – August 13, 2026
g. Pioneer Lead: Braden Henderson
• Disconnections – R.18-07-005:
a. Proceeding Overview
i. Rulemaking 18-07-005 was opened in response to Senate Bill (SB) 598 to address disconnection rates for both California’s electric and gas investor-owned utilities. SB 598 requires the commission to prohibit disconnecting service for nonpayment by a residential customer dependent on life-support equipment, who is willing to enter into an amortization agreement, and who satisfies certain other conditions. The ruling was structured to occur in two phases; the first phase for immediate solutions to reduce disconnections, while the second phase is to evaluate the first phase results and establish long term solutions.
ii. This proceeding requires the IOUs to administer two pilot programs Arrearage Management Plan (AMP) and Percentage of Income Payment Plan (PIPP). The pilot programs are reaching the end of their initial period and are being evaluated for continuation.
b. Potential Impact on Pioneer
i. Pioneer participated in the AMP program and we may have recommendations on how this program may be improved in the event of renewal. Pioneer likely supports [Publish Date] Agenda Date: 9/17/2026

programs that offer assistance to low-income customers or customers facing hardship.
c. Key Issues
i. Disconnections in this proceeding are focused on the event when a utility intentionally disconnects a customer, mainly residential customer nonpayment.

Disconnections due to nonpayment are a concern to regulators, service providers, and other customers because disconnections shift cost burden onto the rest of ratepayers. Programs and pilot programs are put in place to help reduce disconnections by offering assistance to customers with financial challenges. d. Background Documents/ Key Decisions
i. SB 598 - Public Utilities: Gas and Electric Service Disconnections (Sept. 28, 2017):
https://calmatters.digitaldemocracy.org/bills/ca_201720180sb598 e. Status Update
i. November 14, 2025 - CalCCA submitted opening comments in response to the Commission’s request for feedback on the AMP, the CBO Pilot, and the PIPP pilot programs and their respective Final Evaluation Reports. CalCCA’s comments are in support of the continuation of AMP and PIPP, while IOUs have submitted opening comments against renewal of the programs.
ii. March 25, 2026 – Comments were filed following the proceeding’s public workshop.

CalCCA supports continuation of AMP, PIPP, and the current disconnection caps. The IOUs’ opening comments focus on modifying the disconnection caps to allow for more disconnections, sunset of the PIPP program, and refinements to the AMP program. Most parties are in favor of extending the AMP program and do not support continuation of the PIPP program.
iii. April 01, 2026 – Reply comments were filed in response to the comments on the commission’s rule setting workshop. All parties largely hold the positions they established in their opening comments. With most parties in favor of continuation of the AMP program, a successor proceeding is expected to result from this proceeding to have a venue for evaluating the ongoing implementation of AMP and other customer protections.
iv. June 5, 2026 – Two Public Participation Hearings (PPH) on disconnections will be hosted by the Joint IOUs. The PPHs are both scheduled to occur on August 6, 2026; the first will begin at 2pm and the second will begin at 6pm. Additionally, comments on TURN's proposal to lower the temperature threshold for suspending service disconnections from 100 degrees Fahrenheit to 90 degrees Fahrenheit are due June 10, 2026.
v. June 22, 2026 – A Draft Resolution was issued refining the previous regulation which prevented IOUs from disconnecting customers when the 72-hour temperature look ahead is predicted to be above 100 degrees or below 32 degrees Fahrenheit. The new resolution revises the upper threshold based on a heat index, specifically CalHeatScore (CHS) Level 2. CHS Level 2 roughly equates to 94 to 98 degrees Fahrenheit depending on the region’s humidity.
vi. August 13, 2026 – The Commission formally adopted the proposed decision to extend the AMP program’s sunset date to February 1, 2027. This date was selected to align AMP with PIPP’s sunset date and to avoid a lapse in the program if the Commission decides to extend the pilot program further or make it a permanent program.
[Publish Date] Agenda Date: 9/17/2026

f. Key Dates
i. Opening Comments – June 10, 2026
ii. Public Participation Hearing – August 6, 2026
iii. AMP Pilot Program Sunset Date – February 1, 2027
iv. Statutory Deadline – December 31, 2026
g. Pioneer Lead: Braden Henderson
• High-DER Future – R.21-06-017:
a. Proceeding Overview
i. The High Distributed Energy Resource (DER) proceeding is the rulemaking in alignment with the CPUC’s Distributed Energy Resources Action Plan 2.0 which aims to leverage DER planning to help achieve California’s renewable energy targets in the 2022-2026 timeframe. The proceeding is currently conducting Track Two and Track Three.
b. Potential Impact on Pioneer
i. This proceeding’s issues include energization of new customers and distributed resources. Other CCAs (i.e., Redwood Coast Energy Authority) have faced some challenges with the interconnection of loads in their service territory, however this type of interconnection, energization, may not be a priority concern for Pioneer at the moment.
ii. This proceeding is actively evaluating impacts to the distribution grid for increased electric loads from emerging technology such as electric vehicles. In parallel demand response policy and changes to time-of-use (TOU) rates from shifted loads may be of concern to Pioneer.
c. Key Issues
i. For Track Three, the main priorities are grid modernization investments in the near term, the implementation of smart inverters to utilize advanced functionalities for grid services, and the better alignment of planned infrastructure investments with utility distribution planning. Overall, this effort seeks to plan for high penetration of DERs and electrification to drive down costs over time. ii. The commission has resurfaced Track Two of this proceeding. Track Two, focused on the topic of DER Orchestration, was discussed earlier in the proceeding without any resulting decisions or consensus. The Commission is exploring how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value added services.
d. Background Documents/ Key Decisions
i. R. 14-08-013 – OIR Regarding Policies, Procedures and Rules for Development of Distribution Resources Plans, Scoping Ruling (Jan. 26, 2016):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M157/K902/157902794.PDF e. Status Update
i. February 6, 2026 – Following the completion of the IOU’s electrification studies, the assigned commissioner has issued a ruling defining the schedule for Track Three to include an All-Party Workshop, Workshop Report, and Party Comment. [Publish Date] Agenda Date: 9/17/2026

ii. March 23, 2026 – The assigned commissioner issued a ruling requesting comments on how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value added services. Opening comments are expected to question if IOUs are the appropriate parties to operate DER markets, and if there were to be the operators, what guardrails are required. iii. April 20, 2026 – Parties filed opening comments in response to the Track 1 and Track 2 issues regarding orchestration of DERs. Most parties support the objective to implement DER orchestration. However, there is concern from non-IOU parties that the Commission should first establish policies and processes before determining implementation pathways. The Commission also released the schedule for the 2026- 2027 Distribution Planning and Execution process.
iv. July 7, 2026 – The Assigned Commissioner’s Proposal on Flexible Service Connections was released. Primarily, the proposal seeks to require the IOUs to implement a standard offering where each IOU must evaluate whether a flexible connection mitigation approach can safely satisfy the customer’s requested capacity before a ratepayer funded distribution upgrade associated with a customer is considered. This strategy aims to establish long-term flexible service connections enabled by DER orchestration and DER services. v. July 9, 2026 – The ALJ released two Track 2 Workshop Reports on “Distribution System Operator DER Orchestration” and “TSO [Transmission System Operator] - DSO Coordination.” The ALJ has requested comments and reply comments on a set of questions related to how to best establish an IOU-lead DSO DER orchestration program.
f. Key Dates
i. Issuance of Assigned Commissioner Proposal on Track 3 Issues – July 7, 2026 ii. Issuance of ALJ’s Questions on Track 2 Workshop Reports – July 9, 2026 iii. Track Three Opening Comments – July 21, 2026
iv. Track Two Opening Comments – July 27, 2026
v. Track Three Reply Comments – July 28, 2026
vi. Track Two Reply Comments – July 31, 2026
vii. Proposed Decision on Track 3 – Quarter 3 of 2026
g. Pioneer Lead: Braden Henderson
• Distributed Energy Resources – R.22-11-013:
a. Proceeding Overview
i. The Commission issued OIR 22-11-013 to achieve consistency of cost effectiveness assessments, improve data access and use, and consider equipment performance standards for DER customer programs.
b. Potential Impact on Pioneer
i. The CPUC uses the Avoided Cost Calculator (ACC) to determine the primary benefits of DER across Commission proceedings. Pioneer may be inclined to follow this proceeding as the ACC calculates various costs related to items such as generation capacity, energy, and RPSs that may have an impact on electricity rates, portfolio planning, or DER program administration.
[Publish Date] Agenda Date: 9/17/2026

c. Key Issues
i. Currently in Phase I, the proceeding covers DER program cost-effectiveness issues, data access and use, and equipment performance standards. All of the latest updates and decisions related to the ACC fall under this proceeding. d. Background Documents/ Key Decisions
i. R.14-10-003 OIR to Create a Consistent Regulatory Framework for the Guidance, Planning and Evaluation of Integrated Distributed Energy Resources, Scoping Ruling (Jan. 5, 2015):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M143/K990/143990275.PDF e. Status Update
i. March 4, 2026 – The assigned commissioner issued a ruling setting the scope and schedule for Phase Three. Phase Three will be exploring the development and application of the ACC's Guiding Principles.
ii. April 29, 2026 - CPUC staff prepared a proposal on their proposed updates to the 2026 Avoided Cost Calculator. Staff also presented the proposal at a public workshop. At a high level, the proposed updates are to apply a single value to green house gas (GHG) emission reductions capped at the societal cost of carbon. iii. July 31, 2026 – The Commission moved the staff proposal to a Proposed Decision for adopting updates to the Avoided Cost Calculator with some modifications from the staff proposal. Largely, this would update the calculation methodology rather than adopt any new applications for the calculator; the calculator adopts a single electricity-based value for both electricity and natural gas GHGs and adjusts various factors leveraged within the model.
f. Key Dates
i. Opening Comments on the Proposed Decision – August 20, 2026 ii. Reply Comments on the Proposed Decision – August 25, 2026 g. Pioneer Lead: Braden Henderson
• Distributed Energy Resource Interconnections (Rule 21) – R.25-08-004:
a. Proceeding Overview
i. The purpose of this proceeding is to update and improve Rule 21 and associated interconnection procedures concerning the safety and reliability of the electric grid as distributed technologies continue to evolve, promote greater transparency and certainty around interconnection processes, and to contain costs for all ratepayers that use the electric grid.
ii. This proceeding will be conducted in multiple phases. Phase 1 will address issues related to Screens Q and R, interconnection timelines, and the interconnection process and fees for resources that are not interconnecting under the Net Billing Tariff (NBT) or Net Energy Metering (NEM) Tariff.
b. Potential Impact on Pioneer
i. Phase 1 of this proceeding is expected to impact how effectively and efficiently resources can be interconnected through Rule 21. Changes to Rule 21 may impact Pioneer’s ability to procure resources as well as implement programs. Delays in Rule 21 interconnections can have serious impacts to developer’s ability to cost [Publish Date] Agenda Date: 9/17/2026

effectively deploy resources, including biomass generation for Pioneer to procure.

Changes to how residential scale resources are interconnected can also affect future programs Pioneer may wish to administer.
c. Key Issues
i. The primary issue discussed in Rule 21 has been related to Screen Q, costs for interconnection studies, and timeline for interconnection applications. Most stakeholders agree that Screen Q is ineffective as almost all larger projects fail Screen Q and are then required to conduct lengthy and costly interconnection studies. Technology developers are in favor of having a faster and less costly process for interconnecting non-export DER technologies such as backup battery systems.
d. Background Documents/ Key Decisions
i. R.11-09-011 – OIR to Improve Distribution Level Interconnection Rules and Regulations, Scoping Ruling (Jun. 20, 2012):
https://docs.cpuc.ca.gov/PublishedDocs/EFILE/RULC/169188.PDF ii. R.17-07-007 – OIR Streamlining Interconnection of Distributed Energy Resources and Improvements to Rule 21, Scoping Ruling (Oct. 2, 2027):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M196/K476/196476255.PDF e. Status Update
i. January 26, 2026 - Pioneer submitted a motion for party status to participate in this proceeding. Our primary interest will be to ensure that bioenergy resources are included in any reforms of the Rule 21 interconnection process, including reforms to address the current delays in interconnecting resources. A scoping memo providing the scope of issues and schedule for the proceeding is expected in the coming weeks.
ii. March 3, 2026 – The assigned commissioner released a scoping memo for Phase One. Phase One is prioritizing issues related to Screens Q & R, interconnection timelines, and the process for resources not interconnecting through the Net Billing Tariff (NBT) or Net Energy Metering (NEM) Tariff. These issues are significantly related to, but not limited to, the issues seen by biomass energy developers and the BioMAT program. Pioneer has been accepted as a party to the proceeding and will submit comments supporting changes to improve IOU compliance with interconnection timeline requirements.
iii. April 30, 2026 - Parties submitted opening comments regarding updates to Rule 21.

Comments responded to a set of questions defined by the Commission. Notably, the Commission requested input on compliance mechanisms that the Commission should consider for IOUs, which may influence better adherence to interconnection timelines. Pioneer submitted comments recommending the Commission adopt policies that protect interconnection customers from financial and programmatic burdens inflicted by IOU caused interconnection delays. While the IOUs were explicitly opposed to punitive measures for interconnection timeline noncompliance, many non-IOU parties brought forth proposals and concepts related to interconnection timeline compliance mechanisms for the Commission to consider.

Most parties expressed support for reevaluating the screening criteria for Rule 21, largely around Screen Q.
iv. May 29, 2026 – Parties submitted reply comments regarding the potential for Rule 21 updates. Reply comments were generally reflective of each party’s opening comments.
[Publish Date] Agenda Date: 9/17/2026

v. July 14, 2026 – The Commission issued a ruling directing the IOUs to submit Rule 21 interconnection application data to aid the Commission in its evaluation of party comments. The data request largely requests information related to application fees and the time and costs associated with the IOUs handling Rule 21 interconnection requests.
f. Key Dates
i. Opening Comments to Phase One Scoping Memo – April 30, 2026 ii. Reply Comments to Phase One Scoping Memo – May 29, 2026 iii. IOU Responses to Ruling – August 11, 2026
iv. Party Reply Comments – August 28, 2026
g. Pioneer Lead: Braden Henderson
1 Attachment: 3 Communications, Outreach & Customer Care Updates Date: 9/17/2026
NOTABLE ACHIEVEMENTS – JULY/AUGUST 2026
• Release of the Joint Rate Comparison Mailer (JRM) created strong customer reaction, increasing calls, emails, and requests to opt-out. To mitigate opt-out requests, Pioneer launched a “Call Us” campaign on social media, encouraging customers to get an analysis of cumulative savings before leaving Pioneer. Customer care received dozens of comparisons requests, which proved to be an effective method for customer retention.
• Despite concerns about the PCIA and rates, Pioneer received more 5-star Google reviews in recent weeks. Among all California CCAs, Pioneer maintains the highest Google rating, with 4.3 stars and 152 reviews. The next highest ranked CCA has 3.5 stars; the CCA with second highest number of reviews has 46.

WEBSITE: PROGRAM INTEREST REMAINS STRONG
Website traffic was extraordinarily heavy during July and August. Continued interest in customer programs and delivery of the JRM were the primary drivers of website traffic, with the top five pages remaining the same for two consecutive months, though varying in order.

July
• 37,636 page views
• 27,288 users
August
• 34,799 page views
• 21,230 users
Top five pages during this time:

1. AC Tune Up 1. PowerShift Rewards

2. PowerShift Rewards 2. AC Tune-Up

3. GridGen 3. Home

4. Commercial AC Tune-Up 4. GridGen

5. Home page 5. Commercial AC Tune-Up
Sixty percent of website visitors clicked though to the PowerShift Rewards landing page, resulting in 738 new program enrollments from August 11 to 31.

REQUIRED REGULATORY COMMUNICATION
The JRM is a required regulatory mailer created collaboratively by Pioneer and PG&E and provides a comparison of typical residential electric rates, average monthly charges, and generation portfolio contents. It is delivered annually to all customers. The 2026 JRM was delivered to customers during the week of August 24.

While the JRM showed Pioneer’s generation rates are lower than PG&E’s for 2026, it also included the Power Charge Indifference Adjustment (PCIA) fees, which created a higher overall cost for Pioneer compared to PG&E. Release of the JRM triggered a strong reaction from customers.

Messaging and talking points focusing on cumulative savings were created. A NextDoor ad campaign was launched encouraging customers to call Pioneer for a savings analysis – highlighting savings over time with Pioneer. Customer care received dozens of comparisons requests, with the majority of customers requesting a comparison staying with Pioneer.

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COMMUNITY ENERGY

CUSTOMER CARE
July and August were unusually busy months for the call center, largely due to marketing efforts, presence at Nevada County Fair, and release of the JRM.

July August
Call Center
• 328 calls
o Billing inquiry was the most frequent
topic at 15.42%
o NEM was the second most frequent topic
at 11.74%.
• 68 surveys completed with a 91.2%
satisfaction rate
Chatbot
• 303 interactions
• 102 live conversations, with average duration
being 24 minutes, 45 seconds
• Customer satisfaction rating of 4.8/5
Call Center
• 724 total calls
o Billing inquiry was the most frequent
topic at 9%
o General information was the second
most frequent topic at 8.28%
• 178 completed surveys with a 92.1%
satisfaction rate
Chatbot
• 643 interactions
• 174 live conversations (up 138% from July)
• Customer satisfaction rating of 4.2/5
OUTREACH: PIONEER IN THE COMMUNITY
July 2026 August 2026
Tuolumne County Chamber of Commerce networking
event
Colusa County Chamber of Commerce networking
event
Orland Chamber of Commerce networking event
Attended South Placer Rotary meetings
Participated in Grass Valley Farmers Market
Meeting with with Nevada City Chamber of
Commerce leadership
Sponsorships
Red, White and You/Auburn
4th of July event/Nevada City
4th of July event/Colfax
4th of July event /Lincoln
Starry, Starry Night/Sierra Nevada Memorial
Hospital Foundation, Grass Valley
Expansion
City of Sonora City Council
Town of Paradise Town Council
Glenn County Board of Supervisors
City of Willows City Council
Meetings: Sutter County and City of Yuba City
regarding Punjabi and Spanish translation
Met with NREN Staff regarding fair partnerships and
resource-sharing
Met with City of Oroville staff regarding local energy
issues
Monitor City of Oroville City Council meeting
Presentation: Rocklin GRC
Auburn Senior Center (billing seminar)
Sacramento Valley League of California Cities Lunch/
Grass Valley
South Placer Rotary meetings
Met with Auburn Chamber Executive Director
Met with Town of Paradise Vice Mayor Culleton
Loomis Chamber GRC
Sponsorships
Sponsorship and booth - Nevada County
Fair
Placer Unplugged event
Wings and Wheels event / Lincoln

Expansion
Butte County BOS
City of Colusa City Council
Sutter County BOS
City of Oroville City Council
Met with Oroville community leader Brian
Wong
Background briefing: Justin Cheney, interim Orland
City Manager
Met with Oroville City Council Member Janet
Goodson

Programs Support
Meeting with City of Williams City Manager, head of
Finance, and Public Works Superintendent to discuss
GridGen and Solar

SOCIAL MEDIA
Consistent with prior months, the posts generating the most engagement feature real people. Top performing posts:

Facebook Instagram Instagram
Feeding the Foothills Savings Tip Tuesday Historic Colfax Paid social ads and boosting specific
posts, combined with the release of
the JRM, drove significant traffic to
our social media pages during July
and August, with an overall
engagement rate of 31 percent.
• 46,117 views to Facebook Page,
majority from non-followers
• 14,411 views to Instagram Page
There also was a spike in online
commentary, with most comments
taking place in NextDoor. Staff
implemented a rapid response effort
related to the JRM, encouraging
customers to call Pioneer for a
cumulative savings analysis. Online
commentary balanced out, with
customer ambassadors correcting
misinformation.
michael giles 22h - Newcastle
Call and talk to Pioneer. The last time I saw someone slam pioneer I called them and found the slam was very misleading.

I (-) Pioneer Community Energy
2510 Warren Dr Ste B, Rocklin, CA
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Q Like * Helpful
o Dolores Duran-Flores 1w · The Estates Stanford Rnch
Jeff PG&E doesn't want any competition! I like Pioneer and have seen savings with them. When I call, I can talk to someone and they can explain my bill to me. The PG&E bill is so complicated that I appreciated Pioneer's staff walking me through it. I don't know how PG & E gets away with making it harder for Pioneer.

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Q Like * Helpful
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PAID MEDIA PROMOTES PROGRAMS
Pioneer’s continued its ad campaign to support the seasonal AC Tune-Up Rebate and PowerShift Rewards programs, as well as the GridGen program. Ads are running on local sites, digital display, Meta, mobile ad messenger, and search displays. Local site display ads, weather-targeted digital, and mobile ads are performing above industry benchmarks and contributing to increased website traffic and program participation.

EARNED MEDIA
Local reporters continue to reach out to Pioneer for background information and comment, particularly related to expansion.

Outlet Medium Topic Content Audience
Reach
Colusa County Pioneer
Review
Online / Print Biomass Pioneer Energy Invests in
Renewable Biomass
184
Wood Bioenergy Magazine Online / Print Biomass Pioneer Community Energy Secures Six Biomass Power
Purchase Agreements
773
CNBC TV Googe Pre-Pay BondAlphabet's Prepaid Energy Bond with California's Pioneer
Community Energy
200,200
Mymotherlode.com Online / Print Expansion Sonora Council to Hear Update from Pioneer Energy
10,500
KCRA3 on MY58 TV Expansion Sonora Council to Hear Update from Pioneer Energy
13,800
KCRA3 News at Noon TV Expansion Sonora Council to Hear Update from Pioneer Energy
24,500
Action News Now Online / Print Expansion Oroville halts plans for public utility, explores new energy
options
10,300
Hoodline.com Online / Print Expansion Oroville Slams Brakes on OroVerde, Flirts with Pioneer
Power Plan
41,000
Action News Now – 4 pm Online/Print Expansion Pioneer Community Energy coming to Chico by Fall 2027
10,500
Action News Now – 10 pm Online/Print Expansion Pioneer Community Energy on track to start service in Chico
next fall
10,500
Chico Enterprise Record Online/Print Expansion Pioneer Community Energy promises lower rates in 2027
5,000
Oroville Mercury-Register Online/Print Expansion Pioneer Community Energy promises lower rates in 2027
396
San Luis Obispo Tribune Online/Print Expansion Pioneer Community Energy promises lower rates in 2027
21,300

Attachment: 4 Program Updates
Date: 9/17/2026

PROGRAMS SUMMARY
Pioneer Program Webpage
• Reconfiguring the Programs Webpage to include more featured programs for our customers • Enhancing partnership and coordination efforts with NREN (Northern Rural Energy Network) to promote rebates & incentives to our customers
CORE Pilot (Continuous Optimization of Resources and Energy) • Request for Proposals from Consultants due September 18. • Energy efficiency program targeted for large C&I, Ag, Municipal organizations • Implementation partner will act as liaison between customer and energy rebates, educational materials, and energy efficiency environments
AC Tune-Up
• 1,824 applications received since launching on April 1st, nearly 50% more than the number of applications received during the same period of 2025
• Pioneer’s new customer portal, designed to make it easier for customers to track their application status and for staff to track program data, is running effectively. • Season ends on October 1
PowerShift Rewards
• 2026 season ends on October 31
• 3,402 customers are currently enrolled
• This Summer has had milder temperatures resulting in 5 events called this season.

GridGen
• 62 projects completed and received final inspection
• 58 projects completed and received Permission to Operate • 84 customers in the active pipeline
• 571.89 KW of solar capacity installed
• 550,870.17 kWh of clean energy generated since program launched Incentive Finder
• 2,665 searches since January 2026
• Data shows that customer interest in HVAC, home appliance, battery and insulation rebates is strong • Future development of a Commercial Incentive Finder
Hourly Flex Pricing Pilot
• Annual true-up period begins in August, after 12 consecutive months of service • Bill credits expected in October
• Two customers enrolled in the program (19 meters/accounts) LED Discount Lighting
• 32 local retailers are currently participating
• About 100,000 units of inventory sold since program launch • Program remains very popular with customers and retail partners Plf)NEER

COMMUNITY ENERGY
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Pioneer Community Energy
Glossary of Terms
CAISO - California Independent System Operator - a non-profit independent system operator that oversees the operation of the California bulk electric power system, transmission lines and electricity market generated and transmitted by its members (~80% of California's electric flow). Its stated mission is to "operate the grid reliably and efficiently, provide fair and open transmission access, promote environmental stewardship and facilitate
effective markets and promote infrastructure development. CAISO is regulated by FERC and governed by a five-member governing board appointed by the governor.

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

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

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

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

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

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

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

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COMMUNITY ENERGY
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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.