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:
PRESENTATIONS AND RELEVANT MEETINGS ATTENDED BY THE CHIEF EXECUTIVE OFFICER
1. Participated in CalCCA Weekly/Monthly Board meetings.
2. Attended a Placer Business Alliance groundbreaking event for Momentum Roseville Substation.
3. Participated in a meeting with Placer County Transportation Planning Agency.
4. Participated in kickoff meeting with Calpine for contract renewal.
ATTACHMENTS
1. Agenda Planning Document
2. Legislative and Regulatory Report
3. Communications Report
4. Programs Report
5. Strategic Plan Quarterly Progress Report
Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
Calpine Energy Services, L.P. 2/27/2026 Sell Resource Adequacy - Flex 10/1/2026 12/31/2026 $448,750 Morgan Stanley Capital Group 3/9/2026 Buy Energy - Unspecified 1/1/2028 12/31/2030 $117,968,397 Constellation Energy Generation, LLC 3/27/2026 Buy Energy - Unspecified 6/1/2026 12/31/2027 $13,822,975 Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 4-10-26
BOARD OF
DIRECTORS
APRIL 16, 2026
REGULAR MEETING
3:00 PM
SPECIAL MEETING
(following Regular Meeting)
(Post Agenda: April 10)
MAY 21, 2026
REGULAR MEETING
3:00 PM
(Post Agenda: May 15)
JUNE 18, 2026
REGULAR MEETING
3:00 PM
(Post Agenda: June 12)
IN THE FUTURE
Special Meeting
Closed Session
1) Conference with Legal Counsel – Existing Litigation
(GC §54956.9(d)(1))
Rio Bravo Tour Diablo Canyon Tour
Regular Meeting 3:00 PM
Consent 1a Minutes for Approval-MAR 19, 2026 Minutes for Approval-APR 16, 2026 Minutes for Approval-MAY 21, 2026 RES Contract Renewal – Calpine (Koehn) 1b Receive Draft Financials FEB 2026
(Koehn)
Receive Draft Financials MAR 2026
(Koehn)
Receive Draft Financials APR 2026
(Koehn)
RES Yes Energy (Kang)
1c RES Prepay Bond Transaction -
authorize consultants & professional
services agreements (Eckert)
RES goods & services agreement (2540
furniture) (Koehn)
Joint Rates Mailer (JRM)
(Stassi-Vanacore)
JUN Contract Renewals
1d RES Approval of Line of Credit
reallocation to Letter of Credit
Securitization and Working Capital
(Koehn)
Presentation guest: CAISO (in person) FUTURE DATE TBD - guest: Dr. Ahmad Faruqui Regular 2
Authorize the CEO to Explore the
Opportunity for Pioneer to Expand its
Territory to include City of South Lake
Tahoe (action-Eckert)
RES Prepay Bond Transaction
(action-Eckert)
RES FY 2026-27 Budget (action-Koehn) JULY RES IRP (Integrated Resource Plan) (action-Kang)
3 Pioneer 2026 Legislative Policy and
Platform (action-Kang)
guests: (NPA) Erin, Cassandra
FY 2026-27 Budget overview
(discussion-Koehn)
Microgrid Incentive Program (MIP)
Update (discussion-Kang)
SEP RES Expansion Planning
(action- Stassi-Vanacore)
SEP Power Content Label (Stassi-Vanacore)
4 RES approving PCIA Offset Credit for
Large Load Customers APR>DEC 2026
(Koehn)
Electric Vehicle Charging Investment
(action- Stassi-Vanacore)
RES Large Load Policy (action-Kang)
5 BioMAT Projects update
(discussion-Kang)
PCIA hedging (action-Kang) (GOV) Administrative Recommendations (procedural)
6 IT Audit (discussion-Koehn) (GOV) Administrative Recommendations (procedural)
General Function II Chief Executive Officer’s Report
REG Reports:
Leg/Reg; Communications; Programs;
QTRLY Updates requested by the Board
Strategic Plan Objectives
Sponsorship Activity
Chief Executive Officer’s Report
REG Reports:
Leg/Reg; Communications; Programs;
Report items: NEM payments (Gina)
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
7 Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 4-10-26
AUDIT/FINANCE COMMITTEE TO BE SCHEDULED – EARLY MAY
in-person & remote locations IN THE FUTURE
David Ring, Chair
Richard Pearl, Vice Chair
Greg Janda
Gary Petersen
Sean Lomen
o April 7, 2026 Minutes
o FY 2026-27 Operating Budget
o Review Power Prepay Transaction
GOVERNANCE COMMITTEE TO BE SCHEDULED – APRIL
in-person & remote locations IN THE FUTURE – MAY/JUNE
Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o December 17, 2025 Minutes
o Preparing for New Members
o Employee Benefits (Closed Session?)
ENERGY PROCUREMENT REVIEW
AD HOC COMMITTEE
TO BE SCHEDULED - TBD
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Vice Chair
Ryan Carter
Anthony DeMattei
Sean Lomen
o Using Put Options as a PCIA Hedge (JAN-BOARD) Annual Appointment of EPRC Members (2027)
EXPANSION
AD HOC COMMITTEE
TO BE SCHEDULED - TBD
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy, Vice Chair
Suzanne Jones
Lori Parlin
o Selection of Officers through 2026
o South Lake Tahoe
COMMUNITY ADVISORY COMMITTEE
TO THE CHIEF EXECUTIVE OFFICER APRIL 22, 2026 JUNE 24, 2026 Meets on the 4th Wednesday
(even-numbered months)
Attachment 2: Legislative and Regulatory Update
Date: 4/16/2026
Legislative Affairs
• The 2026 Legislative Session began on Monday, January 5, 2026 and is scheduled to end on August 31, 2026. In the near term, Pioneer will meet with its lobbyists, Niemela Pappas & Associates (NPA), to discuss priorities for this session and develop Pioneer’s Legislative Platform to bring to the Board for approval. 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). • March 6, 2026 – Pioneer submitted a letter of support for AB 1761 (Rogers), a bill sponsored by CalCCA that would promote energy affordability and rate stability by improving transparency in how the PCIA charge is calculated.
• March 31, 2026 – Pioneer submitted a letter of support for SB 1138 (Padilla), a bill sponsored by CalCCA that would require the Public Utilities Commission to allow load-serving entities to transact their resource adequacy (RA) load obligation on an hourly basis. This change would be aligned with the granularity of the RA program’s new slice-of-day (SOD) structure, which requires procurement compliance at the hourly, instead of previously monthly, level. Hourly load obligation trading would grant greater flexibility in meeting RA compliance and reduce unnecessary over-procurement which would lower costs for ratepayers.
Plf)NEER
COMMUNITY ENERGY
[Publish Date] Agenda Date: 4/16/2026
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 Standards (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: .......................................................................................... 11 • PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast: ......................... 12 o 2024 ERRA Compliance – A.25-02-013: ............................................................................... 12 o 2025 ERRA Compliance – A.26-02-019 ................................................................................ 13 o 2026 ERRA Forecast – A.25-05-011:.................................................................................... 14 • PG&E General Rate Case (GRC) Phase 1 – A.25-05-009: ......................................................... 14 • PG&E General Rate Case Phase 2 – A.24-09-014: ................................................................... 16 • Provider of Last Resort (POLR) – R.21-03-011: ...................................................................... 18 • CEC Load Management Standards (LMS) – CEC 21-OIR-03; 23-LMS-01: ................................. 19 • Power Charge Indifference Adjustment (PCIA) – R.25-02-005: .............................................. 20 • Safety & Reliability OIR– R.24-05-023: ................................................................................... 22 • Disconnections – R.18-07-005: ............................................................................................... 23 • High-DER Future – R.21-06-017:............................................................................................. 25 • Distributed Energy Resources – R.22-11-013: ........................................................................ 26 • Distributed Energy Resource Interconnections (Rule 21) – R.25-08-004:............................... 27 [Publish Date] Agenda Date: 4/16/2026
• 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. The BioMAT program underwent its final program period ending on March 31, 2026.
Considering the program has effectively ended, this proceeding will be removed from future reports.
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 [Publish Date] Agenda Date: 4/16/2026
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 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 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 – A decision 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. March 26, 2026 – A proposed decision was issued, which shifts the distribution of the residential electric climate credit for large IOUs from April and October, to August and September, on the basis that summer months are typically higher-bill months, in which the CCC 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
[Publish Date] Agenda Date: 4/16/2026
iii. Decision Ordering Immediate Improvements to the CCC to Lower Electric and Gas Bills (March 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M603/K473/603473601.PDF f. Key Dates
i. April 15, 2026 - Opening comments are due on the PD Ordering immediate Improvements to the CCC
ii. April 20, 2026 – Reply comments are due on the PD Ordering immediate Improvements to the CCC
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 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. October 28, 2025 - The CPUC issued the new IRP scoping memo and ruling, setting the deadline for the individual IRP plans to be due May 5, 2026, as well as the scope and schedule for the rest of the proceeding through 2026. ii. January 14, 2025 – The CPUC issued a PD Requiring 2029-2032 Procurement and Transmitting 2026-2027 Transmission Planning Process (TPP) Portfolios. The PD orders LSEs to procure 2,000 MW net qualifying capacity (NQC) by 2030 and additional 4,000 MW NQC by 2032, with no more than half of the total NQC per tranche eligible to come from storage resources, and the rest to come from GHG-free or RPS eligible resources. The procurement need will be allocated based on each LSE's share of the managed peak on the electric system as of the RA year 2026. The [Publish Date] Agenda Date: 4/16/2026
order mostly resembles MTR rules. For TPP portfolios, the PD adopts the base case portfolio which includes half of the upper bound of the LLT resources considered for central procurement by the Department of Water Resources (DWR) and retains offshore wind reported in LSEs' November 2022 IRPs. The PD also adopts the limited wind sensitivity portfolio to be further studied.
iii. February 26, 2026 – The CPUC adopted a revised PD Requiring 2029-2032 Procurement and Transmitting 2026-2027 TPP Portfolios. The final decision requires LSEs to procure 6,000 MW NQC by 2032, in three tranches beginning with 2,000 MW in 2030, 2,000 MW in 2031, and 2,000 MW in 2032. The 50% storage cap on these resources was removed. Instead, the final decision requires at least one-quarter of the procurement by 2032 to come from clean firm and/or long duration energy storage (LDES) resources. The decision included an attachment indicating LSEs load share allocation, stating Pioneer’s share of the procurement order would be 54 MW total by 2032, with 14 MW total to come from clean firm and/ or LDES resources.
The decision also clarifies that RA bridge provisions and “good faith efforts” standards will apply to the procurement order.
iv. March 9, 2026 – The CPUC issued an ALJ ruling granting joint parties’ extension request for the IRP individual filings, extending the deadline from June 1, 2026 to August 10, 2026. Opening comments on LSEs’ IRPs will be due September 21, 2026. 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 f. Key Dates
[Publish Date] Agenda Date: 4/16/2026
i. January 2026 – ALJ ruling containing filing requirements for LSEs for their individual IRPs
ii. February 2026 – Final Decision on Potential Interim Order for Reliability Procurement and 2026-2027 CAISO TPP Recommendations
iii. August 10, 2026 – LSEs' Individual IRP Plans Due
g. Pioneer Lead: Chau Pham
• Renewables Portfolio Standards (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
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. 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
i. June 12, 2026 – Draft RPS Procurement Plan is due
g. Pioneer Lead: Chau Pham
[Publish Date] Agenda Date: 4/16/2026
• 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. 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. December 12, 2025 - a Scoping Ruling was issued with the following items in scope for the Track 1 of the RA proceeding:
• Adoption of local and flexible requirements;
• Accreditation for long duration energy storage;
• Development of the Unforced Capacity Methodology framework; • Accreditation for wind and solar;
• SOD transactability issues;
• Residual Unit Commitment for RA resources
• Energy only resources; and
• Other time sensitive issues identified by the CPUC or parties in proposals ii. January 23, 2026 - CalCCA filed RA Track 1 proposals including 1) using data center interconnection info, instead of data center IEPR forecast, to inform RA requirements, 2) counting of energy only (EO) co-located resources under SOD, 3) ensuring local RA central procurement entity (CPE) data request is used consistently among CPEs to ensure there is no over-procurement, and support publicizing the CPE data request responses.
iii. March 3, 2026 – CalCCA filed an opening proposal on Transactability Issues, responding to ED’s Transactability Report and recommending adoption of hourly load obligation trading. CalCCA argued that the report does not accurately address the issues with the SOD framework or the affordability implications of hourly load obligation trading. CalCCA proposed the CPUC adopt hourly load obligation trading to allow LSEs to transact at the same level of granularity as the SOD requirements and invest in software and systems to automate the RA validation process to assist with administrative burden or adopt temporary guardrails to aid in assessing compliance. iv. March 6, 2026 – CalCCA filed opening comments on Track 1 proposals, clarifying their proposal to incorporate data center load into RA allocations based on specified development milestones, rather than forecasted load. CalCCA also sought procedural [Publish Date] Agenda Date: 4/16/2026
and timeline clarifications on PG&E’s proposal that voluntary changes to the effective date of an LSEs’ CPUC-approved implementation plan does not qualify as “load migration” in the annual RA allocation process. The comments also expressed views on various other party proposals, which Pioneer did not directly engage in. v. March 20, 2026 – CalCCA filed reply comments on Track 1 proposals, providing counterarguments to several parties who raised objections to the data center load allocation proposal and PG&E’s recommendation to reject the proposal to clarify use of the local RA CPE data request. CalCCA also raised objections to Cal Advocates’ long duration energy storage (LDES) counting proposal with similar concerns as multiple other parties that it likely underestimates LDES’ charging capability. vi. March 30, 2026 – CalCCA filed reply comments on Transactability Issues, responding to Vistra’s opposition to hourly load obligation trading (HLOT) and echoing environmental groups’ support of HLOT as a mechanism to promote affordability and reduce reliance on fossil fuels.
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 f. Key Dates
i. January 23, 2026 – Track 1 party proposals
ii. February 23, 2026 –ED report on transactability issues iii. March 3, 2026 – Party proposals on transactability issues iv. May 2026 – Proposed Decision on Track 1
v. Early July 2026 – Final Decision on Track 1
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) will streamline both the negotiation process and the approval process, resulting in faster interconnection timeline.
[Publish Date] Agenda Date: 4/16/2026
b. Potential Impact on Pioneer
i. New large loads, such as data centers, located in Pioneer’s service territory presents both challenges and opportunities to Pioneer. If Pioneer is going to provide generation service to these customers, it needs visibility into which ones 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 in enough in advance for Pioneer to procure resources in advance of any compliance deadlines to serve 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. 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
e. Status Update
i. No updates.
f. Key Dates
i. June 20, 2025 - Intervenor Testimony
ii. August 19, 2025- Rebuttal Testimony
iii. September 22-24, 2025 - Evidentiary Heary
iv. October 24, 2025 - Opening Briefs
v. February 18, 2026 – Limited Opening Testimony on additional cost allocation questions in a January 9, 2026 Ruling
vi. March 13, 2026 – Rebuttal Testimony on additional cost allocation questions [Publish Date] Agenda Date: 4/16/2026
vii. April 1, 2026 – Evidentiary Hearings, if needed, on additional cost allocation viii. questions
ix. April 10, 2026 – Opening Briefs on additional cost allocation questions x. April 24, 2026 - Reply Briefs on all issues
xi. Late July 2026 – Proposed Decision
xii. August/September 2026 – CPUC Decision
g. Pioneer Lead: Lee Ewing
• 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 is dual participation of DR resources among different programs, adjustments to the DR guiding principles, and integration into other systems and process, 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. A Ruling and a Staff Proposal on IOU DR program bridge funding were issued March 10, 2026. The Staff Proposal recommends that 2027 IOU DR program implementation be funded and extended through 2028 and 2029, putting off the next program cycle by two years (making it2030-2034). The Staff Proposal also recommends delaying the IOU DR program application from November 2026 to January 1, 2029, to incorporate updates that come from this proceeding. ii. D.26-03-016 was issued on March 26, 2026, authorizing the continuation of the Flex Alert media campaign program for 2026 with a budget of $15 million. e. Background Documents/ Key Decisions
i. Order Instituting Rulemaking (Sept. 18, 2025) (including the Demand Response Guiding Principles Staff Report):
[Publish Date] Agenda Date: 4/16/2026
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 15, 2026 – Opening Comments on Bridge Funding Staff Proposal Ruling ii. May 6, 2026 – Reply Comments on Bridge Funding Staff Proposal Ruling iii. Q2 2026 - Staff Proposal on Data Systems and Processes iv. Q3 2026 – Proposed Decision on IOU DR Bridge Funding v. Q4 2026 – Proposed Decision on all other issues
g. Pioneer Lead: Lee Ewing
• PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast:
o 2024 ERRA Compliance – A.25-02-013:
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.
b. 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.
c. Status Update
i. No updates.
d. 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 [Publish Date] Agenda Date: 4/16/2026
e. 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 f. Pioneer Lead: Lee Ewing
o 2025 ERRA Compliance – A.26-02-019
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.
g. 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.
h. Status Update
i. PG&E filed its 2025 ERRA Compliance Application on February 27, 2026. ii. CalCCA filed a Protest of PG&E’s Application on April 2, 2026. Typically, Protests in this proceedings simply request that the Commission set the matter for a hearing to allow parties more time to examine the issues raised by the Application. However, here, CalCCA raised the additional issue of examining PG&E’s vintaging practices based on consistent errors by PG&E in vintaging new CCA customers. i. 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 j. Key Dates
[Publish Date] Agenda Date: 4/16/2026
i. To be determined in a forthcoming Scoping Ruling.
k. Pioneer Lead: Lee Ewing
o 2026 ERRA Forecast – A.25-05-011:
a. Proceedings Overview
i. ERRA Forecast Applications are filed annually by IOUs to forecast energy procurement-related revenue requirements, which includes forecast allocation of costs across Power Charge Indifference Adjustment (PCIA) vintages. b. Potential Impact on Pioneer
i. 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.
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. 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: Lee Ewing
• 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 [Publish Date] Agenda Date: 4/16/2026
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 overhaul of these facilities, supporting life extensions as well as changed functions for these assets.
ii. The ALJ issued a Scoping Ruling asking questions related to the implementation of AB 2666, which aims to better understand the real rate of return utilities receive using backwards looking reviews in GRCs. Though the bill went into effect at the beginning of 2025, this is the first instance of the CPUC addressing the new requirements. The Ruling requests party views on whether and how to scope implementing AB 2666, including whether the GRC is the right venue or a separate rulemaking. Though AB 2666 will improve transparency in general, it is unlikely to make meaningful changes on our primary issues at hand (i.e. PCIA vintaging of hydro assets and assets that are no longer used and useful). Comments on the Ruling are due March 17, 2026.
iii. CalCCA filed Opening Comments on March 17, 2026, recommending that implementation of AB 2666 be discussed in a separate rulemaking with all the IOUs to address the matter consistently and efficiently across all three IOU territories [Publish Date] Agenda Date: 4/16/2026
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: Lee Ewing
• 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).
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
[Publish Date] Agenda Date: 4/16/2026
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. CalAdvocates Testimony -January 9, 2026
ii. Intervenors' Testimony – March 9, 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: Lee Ewing
[Publish Date] Agenda Date: 4/16/2026
• 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:
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: Lee Ewing
[Publish Date] Agenda Date: 4/16/2026
• CEC Load Management Standards (LMS) – CEC 21-OIR-03; 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. No updates.
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
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 [Publish Date] Agenda Date: 4/16/2026
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: Lee Ewing
• 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 revintaging 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
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)
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 [Publish Date] Agenda Date: 4/16/2026
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 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. In Response to a Ruling requesting comments on issues to be addressed in Track 3, CalCCA submitted comments on March 27, 2026, stating that:
[Publish Date] Agenda Date: 4/16/2026
• Track 3 should be scoped to accomplish the OIR’s objective of broad improvements to ERRA and PCIA rules;
• The broad scope of Track 3 necessitates that all stakeholders first have access to an equally broad range of data for meaningful participation; • The Commission should adopt the 2017 data access protocol with updates to ensure Track 3 issues and proposals can be adequately addressed; and • Track 3 should be phased to resolve the data access issues prior to addressing all other 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 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. A schedule for Track two will be established in a forthcoming Scoping Ruling, but it is expected to be a protracted proceeding that extends into 2028. g. Pioneer Lead: Lee Ewing
• 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 outage causes 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 [Publish Date] Agenda Date: 4/16/2026
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
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 OK 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. f. Key Dates
i. Joint IOU Report Template – December 15, 2025
ii. Opening Comments – January 9, 2026
iii. Reply Comments – January 26, 2026
iv. Proposed Decision - No later than 90 days after final submissions v. Final Decision - No sooner than 30 days after Proposed Decision 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.
[Publish Date] Agenda Date: 4/16/2026
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 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.
f. Key Dates
i. Public Rule Setting Workshop – March 11, 2026
ii. Opening Comments to Rule Setting Workshop– March 25, 2026 iii. Reply Comments to Rule Setting Workshop – April 01, 2026 iv. Statutory Deadline – December 31, 2026
g. Pioneer Lead: Braden Henderson
[Publish Date] Agenda Date: 4/16/2026
• 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 DER interconnection 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. January 2, 2025 – CalCCA submitted reply comments in response to the IOU’s electrification studies and opening comments to emphasize that the IOUs should reevaluate their assumptions and prepare updated analysis that reflects realistic use of demand flexibility programs. Included in this is also recommending the IOUs roll out pilot programs to better understand realistic adoption rates; PG&E agreed with CalCCA on this topic in their reply comments.
ii. 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. iii. March 23, 2025 – 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. [Publish Date] Agenda Date: 4/16/2026
f. Key Dates
i. Track Three All-Party Workshop – February 20, 2026
ii. Track Three All Party Workshop Report – March 2, 2026 iii. Tack Three Party Comment on Workshop Report - April 3, 2026 iv. Track Two Comments – April 13, 2026
v. Track Two Reply Comments – April 20, 2026
vi. Track Two Workshop – April 29, 2026
vii. Issuance of Assigned Commissioner Proposal on Track 3 Issues – Quarter 2 of 2026 viii. 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.
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.
f. Key Dates
i. ACC Update Staff Proposal Published - April of 2026
ii. Opening Comments – May 2026
iii. Reply Comments - May of 2026
iv. Proposed Decision Adopted - August of 2026
[Publish Date] Agenda Date: 4/16/2026
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 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 [Publish Date] Agenda Date: 4/16/2026
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.
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 g. Pioneer Lead: Braden Henderson
1 Attachment 3: Communications, Outreach, and Customer Care Updates Date: 4/16/2026
NOTABLE ACHIEVEMENTS – MARCH 2026
WEBSITE
The Pioneer website was updated to better optimize navigation and improve user experience.
Changes, including image updates, keep the site “current” and in line with the recent best practices.
With 7,200 users, website traffic increased, likely due to an e-blast distributed in mid-March (which caused a 251% spike in the number of users-per-day in the days following its release). During March,
53.2% of users were male; 46.8% were female. The average viewing session lasted 2 minutes, 31 seconds.
Top five pages visited:
• Home
• Incentive Finder
• AC Tune-Up Rebate
• PowerShift Rewards
• Residential Programs
CUSTOMER CARE
Pioneer’s 2026 rates went into effect on March 1, as did PG&E’s Base Services charge. The number of calls remained steady from month to month, while chatbot activity increased. Customer satisfaction ratings remain high in both areas.
Calls
• 416 total (slight decrease from February, which had 422 calls but fewer days in the month) o Billing Inquiry was the most frequent topic at 16.36% and Net Energy Metering was the second most frequent at 10.45%.
• 83 surveys completed with a 91.6% satisfaction rate
Chatbot
• Total of 271 interactions
• 83 live conversations (up 26% from February)
• Rating of 4.6/5 in satisfaction surveys
• CEO Eckert’s appointment to the influential
Greater Sacramento Economic Council
elevates Pioneer’s presence on a regional level
and was promoted by GSEC on LinkedIn and
Facebook, with engagement from several
regional leaders.
• Community outreach efforts in current and
expansion communities resulted in nearly 200
contacts with new members and a variety of
community organizations.
Plf)NEER
COMMUNITY ENERGY
Greater Sacramento Economic Council
13.011 followers
1w• ®
We're thrilled to welcome four new leaders to our Board who will help guide our mission and strengthen collaboration across Greater Sacramento I< • Donald Eckert Jr., CEO. Pioneer Community Energy
• Mayor Kelley (Colditz) Davis, MS. RD. City of Auburn. CA • Mayor Justin Raithel, City of Folsom
• Mayor Garrett Gatewood, City of Rancho Cordova
Each brings a unique perspective and a shared commitment to advancing economic growth and opportunity across the region. Together, we're building a stronger, more connected Greater Sacramento.
Meet our full BOD: https://lnkd.in/eNgsxBGU
Webinar Series
To further serve customers, staff kicked off the first in a series of customer education webinars on March 20, beginning with “Money Saving Programs.” Other planned webinars include “What is NSC?” (timed to educate NEM and SBP customers about the details of annual true-ups), “Ways to Save,” and an updated “Who Is Pioneer?” (which will be conducted later this year and include details for expansion communities).
PIONEER IN THE COMMUNITY
Community Outreach
• Attended regional Government Relations Committee meeting • Regional Economic Development Stakeholders Quarterly meeting – shared programs information • Loomis Chamber meeting- shared programs information
• Monitored PG&E Town Hall meeting
• Attend Lincoln Townhall meeting with Senator Niello and Supervisor Landon • Attended South Placer Rotary meeting
• Attended Rocklin Chamber Breakfast
• Attended Chamber Sunrise meeting
• Attended El Dorado County Chamber meeting
• Sierra Meeting in Tuolumne County
• PCTPA EV Webinar - review of Draft ZEV Infrastructure • Attended Climate Readiness Collaborative
• Meeting with Nevada City Chamber of Commerce
Expansion
• Met with City of Oroville City Administrator and Economic Development Manager to share information about member programs and discuss OCDC biomass workshop
• Oroville Community Economic Development Meeting and Tour • Yuba Sutter Chamber Member Orientation
• Contacted expansion communities about GridGen, Solar RECs, and Clean Fleet Revenue
• Met with Yuba City Manager regarding Pioneer programs • League of California Cities Meeting, Chico
• Contacted expansion school districts regarding programs • Met with Tuolumne County Supervisors, Sonora City Council, Sheriff and County Staff
• Attended OCDC event with Chico Enterprise-Record and Oroville Mercury-Register
Program Support and Promotion
• Meeting with Placer County, General Services Director to discuss Pioneer and programs
• Contacted 50 special districts, water agencies, school districts with programs information • Met with City of Yuba City, City of Auburn, City of Rocklin, and Newcastle/Rocklin/Goldhill Cemetery District, Placerville and Colfax
• Programs mailing to general contractors
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SOCIAL MEDIA
Social media engagement for March was higher than usual. Staff has been vigilant about monitoring comments on social media (”social listening”) to correct misinformation. Notably:
• Reactions to Pioneer posts had 100% positive sentiment during March. • More customers are engaging on Pioneer’s behalf to keep facts accurate. • Many customers are sharing AI-generated responses, and the responses are correct and positive.
Top performing posts for March:
FACEBOOK INSTAGRAM LINKEDIN
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PIONEER COMMUNITY ENEQOY
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■ Great er Sacramento Eco nomic Council
13,083followers
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We're thrilled to welcome four new leaders to our Board who will help guide our mission and strengthen collaboration across Greater Sacramento "° • Donald Eckert Jr .. CEO. Pioneer Community Energy
• Mayor Kelley (Colditz) Davis, MS, RD, City of Auburn. CA • Mayor Justin Ra ithel. City of Folsom
• Mayor Garrett Gatewood, City of Rancho Cordova
Each brings a unique perspective and a shared commitment to advancing economic growth and opportunity across the region. Together. we're building a stronger, more connected Greater Sacramento.
Meet our full BOD: https://lnkd.in/ eNgsxBGU
Darr~l l'eet
I just did this far mine - 1 used the prompt 'does pioneer add a net benefit or add tomycosts'; this is theresponse:
Based on current 2026 da1a and your specific account profile, having Pioneer is generally a ··net benefit .. , but the ·savings" are mon! nuanced than a simple lower bill.
Here is the breakdown of how it affects your costs
### 1.TheDirectDiscount(Generation)
Pioneer's Board rN:!'ntly approved a "10% discount" compared to PG&E's generation rates (Of 2026. This is the third consecutive year they have lowered rates to stay competitive
• "The "Catch":" You still have to pay a "PCIA fee .. (Power Charge Indifference Ad;ustment) lo PG&E. This is an "el!it lee' PG&E charges to cover power they bought on your behalf before you switched to Pioneer.
• "The Result:" When you add the Pioneer rate + the PCIA fee. the totJI cost per kilowatl·hour usually ends up being .. very similar to (or slightly cheaper than)·· what you would pay if you were 1 OO'l6 with PG&E.
### 2. The Solar Advantage (NEMJ
Since you are a solar customer (as shown by your "S 129.00 True-up estimate"}, Pioneer offers a specific benefit Iha! PG&E does not
• "Higher Buy-Back Rate:" If you ever produce more power than you use in a year. Pioneer pays you a ··S0.005 (l/2 cent) premium·· per kilowatt-hour on top ofPG&E'sstandardM.irplus rate.
~ .. cash-Out Ch eds:•• Unlike PG&E, which often just rolls over credits, PiOl)()er sends out "physical checks .. every spring if your credit balance is over 550. In 2025, they paid out over S 1 million to local solar custome-f'S t••3.lmpactof the "BaseServicHCharge·
You likely noticed the alert on your dashboard about the •• Base Services Charge•• starting in March 2026.
• This is a .. PG&E delivery charge", not a Pioneer lee • Because this new fixed charge (524.11 for most residential custornen) lowers the overall price per kilowo1tt-hour, it c1etuo1lly makes the "generation" portion of your bill-where Pioneer saves you money-a smaller piece of the 101111 pie.
Attachment: 4 Program Updates
Date: 4/16/2026
Seasonal Programs
Pioneer’s seasonal programs launched on April 1 with the AC Tune-Up Rebate; PowerShift Rewards launches on May 1. Staff created and distributed promotional materials for all programs, with an emphasis on these two.
AC Tune-Up
• Launched on April 1st
• 21 applications received during the first week
• E-blast to business customers and presentations to local Chambers of Commerce promote program expansion to C&I customers
• 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 up and running effectively.
PowerShift Rewards
• 2026 season launches on May 1
• Early promotion underway to our existing 2,516 enrolled customers GridGen
• 42 projects completed and received final inspection
• 37 projects completed and received Permission to Operate • 82 customers in the active pipeline
• 418.52 KW of solar capacity installed
• 180,030.69 kWh of clean energy generated since program launched • All expansion communities have been contacted regarding the expiration of federal rebates and encouraged to participate in the program
• Staff remain focused on expanding the program to commercial and industrial, and member agencies o All member agencies have received information about the program. Placer County, Rocklin, Yuba City and Newcastle/Gold Hill/Rocklin cemetery district have expressed interest o Initial data analysis being conducted for the City of Placerville LED Discount Lighting
• 29 local retailers are currently participating, including one national partner (Lowe’s) • Nearly 100,000 units of inventory sold since program launch • Program remains very popular with customers and retail partners Incentive Finder
• Webpage has been the second most visited page for two consecutive months • Initial results are positive and traffic continues to increase • Most visited incentives are related to rebates, energy efficiency kits, and Pioneer programs Clean Fleet Revenue
• Participating members include Rocklin and Nevada City; City of Auburn pending Solar Renewable Energy Credits (RECs)
• Ongoing and extensive outreach to current and expansion members • Staff met with the Counties of Placer and El Dorado, Cities of Lincoln, Rocklin, Oroville, and Yuba City o Initial data analysis being conducted for the City of Placerville • Staff have initiated outreach to additional eligible entities (e.g. Special Districts, School Districts, etc.) Ice Energy
• Finalizing Participation Agreement with the City of Rocklin which includes approximately 23 units • Bank of America B has four sites interested; they have sustainability mandates to reduce load and shave during peak hours. Ice Energy is expected to survey all sites Plf)NEER
COMMUNITY ENERGY
Agenda Item: XX Agenda Date: 4/16/2026
Hourly Flex Pricing Pilot
• Two customers enrolled in the program (19 meters/accounts) • The program is administered by PG&E
• The application period for the program remains open, however incentives for eligible equipment already have been allocated
Community Advisory Committee (CAC)
• Next meeting is April 29
• The plan was adopted in September 2024
• Five (5) Strategic Goals to support the
Mission and Vision
1. Be a Community Partner
2. Be Fiscally Strong & Resilient
3. Provide Exceptional Customer Service
4. Achieve Operational Optimization
5. Be a Great Place to Work
• Quarterly report focuses on progress the
past quarter and current/future work
Community
Partner
Operational
Optimization
100
Fiscally
Strong &
Resilient
Great Place to
Work
Exceptional
Customer
Service
Overall
• Re-launching seasonal programs April 1st
including approval from the Board to expand
the HVAC Rebate Program to include
Commercial & Industrial accounts
• Active in communications to Member Agencies
on monetization of solar renewable energy
credits, GridGen program, and low carbon fuel
standard credits
• Pioneer joined the Great Sacramento Economic
Council Board
• Adopted FY 2025-26 Mid-Year Budget resulting
in a balanced budget and no withdrawal from
reserves
• Kicked off Prepay Bond process allowing
Pioneer to use tax exempt status to save
money on power supply costs
• Achieved strong results for annual financial
audit
Provide Exceptional Customer
Service
• Adopted rates for 2026 that included a 16°/o
reduction in Pioneer's rate while balancing
rate competitiveness with sustainability
• Website updates to improve user experience
and optimize navigation
• Conducted webinar for customers focused on
solar customers understanding of Net Energy
Metering/Solar Billing Plan rates
Achieve Operational
Optimization
• Completed annual IT audit and received a
strong report
• Staff achieved 100% grade for no phishing email
breaches
• Achieved six PPAs under the BioMAT program
that invest in community scale biomass
projects in the region at minimal impact to
our ratepayers
• Application submitted for Microgrid Incentive
Program that includes four site locations in
our service territory
• Achieved "Great Place to Work" certification
• Volunteer event at Feeding the Foothills that
involved 70°/o of the staff participating
• Completed employee survey and achieved
>80°/o satisfaction rate from employees
• Employees feel aligned with the mission and the . . v1s1on • Employees feel satisfied with the culture, health
and welfare benefits
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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.