Pioneer Community Energy Board of Directors
October 15, 2026

Amended: May 15, 2025
GAP1
Category: General Administrative
Page | 2 Proposed: February 18, 2021

EXPANSION POLICY
Whereas Pioneer Community Energy (Pioneer) seeks to continue providing the benefits of Community Choice Aggregation (CCA Benefits) to its members through:

1. Local Control over Rate Stability and Competitiveness.

2. Local Control over Procurement, Investment, and Jobs Creation.

3. Local Control over conducting Programs to reduce energy consumption; and

4. Local Representation in Regulatory and Legislative Affairs.

Whereas Pioneer can help ensure that its members receive ongoing CCA Benefits through establishing policies and procedures that promote a fiscally sound organization.

Whereas one of the key drivers of a fiscally sound organization is a Reserves Policy that provides adequate reserves for Pioneer to provide the CCA Benefits; and
Whereas the addition of new communities to Pioneer will contribute towards reserves and give Pioneer greater flexibility in providing CCA Benefits.

Therefore, it is Pioneer’s policy to explore and support electric service in new communities to further the agency’s goals.

In consideration of the above, Pioneer will allow access to service in new communities under the following criteria:

1. Addition of the new community must improve Pioneer’s net margin. a. Pioneer will not subsidize any applicant.

2. Applicant must be aligned with Pioneer’s goals as stated in CCA Benefits above

3. Applicant must agree to Pioneer’s “one member one vote” policy. a. No weighted voting

4. Applicant must agree to Pioneer’s “New Member Reserves Policy.” a. Previously funded reserves were unavailable for Applicants.

5. Applicant agrees to equally share the cost of an Impact Assessment Study that determines the projected fiscal impact on Pioneer’s net margin.

GAP1
Category: General Administrative
Page | 2 Proposed: February 18, 2021
Pioneer Membership Process
Step 1: Applicant Governing Body submits letter to Pioneer requesting consideration as a member.

Step 2: Staff evaluates request timing to determine if internal resources are available to consider request, and to ensure no impact on core agency functions.

Step 3: Applicant request is submitted to Pioneer’s Executive Committee to review whether the criteria described above have been met.

Step 4: Following Pioneer Board approval, the Chief Executive Officer executes contract (e.g., Memorandum of Understanding) with governing body of Applicant to fund costs of Impact Assessment. Staff undertake and completes analyses, with primary focus on net margin analysis.

Step 5: Results of Impact Assessment presented to the Executive Committee, Pioneer Board, and governing body of Applicant. If the results are positive:

1. Governing body of Applicant approves resolution requesting membership, and ordinance authorizing CCA service through Pioneer; and

2. Applicant may move forward with Pioneer membership process pursuant to requirements of the JPA and the Public Utilities Code Step 6: Pioneer Board considers adoption of resolution amending its JPA to add new member and considers approval and submission of Amended Implementation Plan to the California Public Utilities Commission.

FP1
Category: Finance
Page | 1 Adopted: August 20, 2020 (Resolution 2020-12)
Updated: January 20, 2022 (Resolution 2022-3)

AUDIT & FINANCE COMMITTEE
I. PURPOSE
The Governing Board appoints the Audit and Finance Committee to, among other things:
• Oversee the accounting and financial reporting process and the audit of the Agency’s financial statements by the
independent auditor; and
• Budgeting and financial planning; and
• Accountability policies and investments; and
• Monitoring of internal controls.

II. REPORTING
The Audit and Finance Committee reports directly to the Governing Board.

III. COMMITTEE MEMBERSHIP
The Audit and Finance Committee must not result in membership that would constitute a majority of the Governing Board. The Governing Board shall appoint the members of the Audit and Finance Committee annually. Eligible Members to serve on the Audit and Finance Committee shall be Board members, Alternate Board members, and Member Agency Staff. No more than one eligible Committee Member shall represent their respective Member Agency. The Audit and Finance Committee shall designate the chairperson and vice chairperson.

IV. COMMITTEE AUTHORITY and RESPONSIBILTIIES
The Audit and Finance Committee shall meet as often as it determines necessary or appropriate to fulfill its responsibilities, but no fewer than twice annually – once to review the audit plan and once to review the audited financials, and related documents, and to review the audit engagement, special investigations, financial irregularities and internal control failures. The Audit and Finance FP1
Category: Finance
Page | 2 Adopted: August 20, 2020 (Resolution 2020-12)
Updated: January 20, 2022 (Resolution 2022-3)
Committee will be a Brown-Acted meeting. The following are the specific functions of the Audit and Finance Committee:

1. The Committee shall annually retain or renew the
appointment of an independent auditor to conduct the audit and any related management letter.

2. Review with the independent auditor the scope and planning of the audit prior to its commencement.

3. Upon completion of the audit, review and discuss the following with the independent auditor:
a. The independent auditor identifies any material risks and weaknesses in internal controls.
b. Any restrictions placed on the independent auditor’s scope of the activities or access to requested
information.
c. The adequacy of the Agency’s interim and annual
accounting and financial reporting process
d. Any recommendations made by the independent auditor

4. Report to the Governing Board of the Committee’s activities and recommend the results of audit findings for approval.

Additional Responsibilities

1. Budgeting and Financial Reporting
a. Develop an annual operating budget with staff.
b. Set long-range financial goals along with funding
strategies to achieve them.
c. Monitor adherence to the budget.
d. Develop multi-year operating budgets that integrate
strategic plan objectives and initiatives.

2. Internal Controls and Accountability Policies
a. Create, approve, and update (as necessary) policies
that help ensure the assets of the agency are
protected.
b. Ensure approved financial policies and procedures are being followed.
c. Developing other policies that further serve to protect the Agency include:

FP1
Category: Finance
Page | 3 Adopted: August 20, 2020 (Resolution 2020-12)
Updated: January 20, 2022 (Resolution 2022-3)
i. Long-term contracts or leases
ii. Loans or lines of credit
iii. IT security
iv. Capital purchases
v. Insurance requirements and reviews
vi. Records retention

3. Investments
a. Draft an investment policy detailing the objectives of the investment portfolio and guidelines on the asset
allocation of the portfolio based on a predetermined
level of risk tolerance.
b. Review the policy at least annually and update if
necessary.
c. Monitor investment returns.

V. LIMITATION OF AUDIT and FINANCE COMMITTEE’S
ROLE
The Audit and Finance Committee is not responsible for planning or conducting audits. The independent auditor is responsible for planning and conducting audits. Neither is the committee responsible for (1) preparing and fairly presenting Pioneer’s financial statements in accordance with generally accepted accounting principles, (2) maintaining effective internal control over financial reporting, nor (3) ensuring Pioneer is in compliance with applicable laws, regulations, and other requirements. These responsibilities are management, and the independent auditor and the committee have independent and complementary oversight responsibilities for determining that the related objectives of management’s responsibilities, as described, are achieved.

Staff Report – Item 3
To: The Governing Board
From: Sam Kang
Item 3: Response to Liberty Utilities Request for Proposal Related to Power Supply Requirements
Date: 10/15/2026

RECOMMENDATION
Receive an update of Pioneer Community Energy’s (“Pioneer”) response to Liberty Utility’s (“Liberty”) Request for Proposal (“RFP”) related to power supply requirements and an overview of strategic steps to include Liberty’s customers into Pioneer’s Joint Exercise of Powers Agreement.

BACKGROUND
SLT has reached out to Pioneer on many occasions throughout the past several years inquiring about membership. Pioneer has not pursued expansion to SLT because it is in Liberty’s (a small investor-owned utility) service territory which does not have a clear path for community choice aggregation (CCA) membership because it has not yet been established by the California Public Utilities Commission (CPUC). There are many other challenges to overcome for CCA membership as well, including the fact that the current energy supplier would have to be willing to forfeit that role, and the possible stranded costs associated with any procurement or utility-owned generation (UOG). During the course of Pioneer’s conversations with SLT, their energy supply was supplied by Liberty who had outsourced that role to NV Energy.

On March 20, 2026, Liberty notified the CPUC that NV Energy will discontinue providing energy supply after May 2027 to instead meet increasing energy demands from data centers in Nevada. NV Energy’s decision means that Liberty must find replacement power for their entire California load, which includes SLT and the 3 Counties.

That same day, the SLT contacted Pioneer to inquire about becoming a Pioneer member and/or if there is a way that Pioneer may be able to help provide power after May 2027.

On August 3, 2026, Liberty issued an RFP for energy supply for their entire California load to replace NV Energy starting January 1, 2028.

ANALYSIS & DISCUSSION

RESPONSE TO RFP
Liberty’s RFP seeks a new supply arrangement that includes firm energy, renewable energy certificates (RECs), and resource adequacy (RA) together with scheduling for its California load in NV Energy’s balancing area.

Pioneer’s interest in participating in this RFP is to demonstrate that we are serious about expanding to SLT and the 3 Counties. The following is a high-level summary of the proposal:
• Pioneer is submitting a joint proposal with Mercuria1, an investment-grade rated power marketer in its proposal to offer a 5-year agreement
• Mercuria would procure and schedule the energy and resource adequacy components because Pioneer has no experience in procuring energy in the NV Energy balancing area but Mercuria does
1 Mercuria is a wholly owned subsidiary of Mercuria Energy Group Ltd (Geneva, Switzerland), one of the world’s three largest independent energy and commodity trading groups with over $100 billion in annual revenue Agenda Item: 3 Agenda Date: 10/15/2026

• Pioneer would procure the RECs for Liberty as Pioneer has deep expertise in this area and an existing portfolio to draw from – REC procurement would be pursuant to CPUC RPS requirements
• During the course of the 5-year contract, any city or county that wants to join Pioneer can go through the process of doing so (to be established by CPUC) • If the CPUC accepts Pioneer’s Amended Implementation Plan, any energy and capacity would be assigned over to Pioneer
• Initial offer will be based on indicative pricing and will allow Pioneer to back out of the offer prior to December 18, 2026
The total estimated notional risk is minimal and averages $777,800 per year over a 5-year term. There will be no market risk as Pioneer will either source the RECs from its own portfolio and/or procure back-to-back volumes. Mercuria has an investment grade Baa2 credit rating from Moody’s and its parent company has over $100 billion in annual revenue. In summary, supplying RECs to Liberty is an important first step in being SLT and the 3 Counties’ energy partner with minimal risk.

BEGIN PROCESS FOR SLT AND 3 COUNTIES TO JOIN PIONEER
Two main items need to be addressed before any of Liberty’s customers can join Pioneer:

1. Liberty needs to file an application for ratemaking with the CPUC; and

2. The CPUC needs to establish a process by which a city and/or county in Liberty territory can join a CCA.

Application for ratemaking: Although Liberty is under CPUC jurisdiction, they currently operate within the NV Energy balancing authority area and not the California Independent System Operator (CAISO) area. Unlike the investor-owned utilities in CAISO service territory, there is no clear process on how a city or county in a non-CAISO utility service area would join a CCA.2 In order to establish the process for CCA membership in Liberty’s service area, they would need to file an application for ratemaking which would define the components of the electricity generation rate including power charge indifference adjustment (PCIA) and any other exit fees – it is unlikely there would be a PCIA for departing load because the incumbent energy service provider is ending service and the UOG is known and easily accounted for.

Pioneer could ask Liberty to file an application for ratemaking, but it would be more convincing if SLT and the 3 Counties did so with a joint request because they make up approximately 92% of their load. Before Pioneer makes the request to SLT and the 3 Counties to submit a joint request, Pioneer should do a feasibility study to make sure that the forecasted rates justify the expansion for both Liberty and Pioneer. If the feasibility study proves positive, staff will proceed with requesting SLT and the 3 Counties to request Liberty to file an application for ratemaking.

CPUC needs to establish a process by which a city and/or county in Liberty territory can join a CCA: Further, if the feasibility study is positive, Pioneer will also move forward with the normal expansion process (e.g., Pioneer Board and expansion city/county approvals) and file an Amended Implementation Plan for expansion.

Staff had initial conversations with the CPUC on whether the process for expansion in Liberty territory is the same as in PG&E territory pursuant to Resolution E-4907, and the answer was that it was uncharted waters.

They suggested that Pioneer file an Amended Implementation Plan for the CPUC to get started on figuring out the process for Liberty service area. If the feasibility study proves positive and moves forward with the normal expansion process, Pioneer will file an Amended Implementation Plan that includes, if interested, SLT and the 3 Counties.
2CPUC Resolution E-4907, adopted by the CPUC on February 9, 2018, establishes a formal registration and review process for CCAs in CAISO service territory to manage Resource Adequacy (RA) obligations and prevent cost-shifting to bundled utility ratepayers.

Agenda Item: 3 Agenda Date: 10/15/2026

Through this dual-pronged approach, Pioneer should be able to understand the feasibility, and process of expanding to Liberty’s service territory.

STRATEGIC PLAN
The recommendation supports the strategic goals to Be Fiscally Strong and Resilient and Be a Community Partner.

FISCAL IMPACT
There will be cost associated with consulting fees but difficult to estimate at this phase.

ATTACHMENTS
None.

Pioneer Community Energy
Energy Procurement Review ad hoc Committee
Committee Members
Ryan Carter
Chair
Alice Dowdin Calvillo
Vice Chair
City of Auburn
Alice Dowdin Calvillo
Sandra Amara, Alternate
City of Colfax
Sean Lomen
Kim Douglass, Alternate
County of Placer
Anthony DeMattei
Bonnie Gore, Alternate
City of Placerville
Ryan Carter
David Yarbrough, Alternate

SUMMARY REPORT
 The Energy Procurement Review ad hoc Committee convened on October 2, 2026, with a quorum of members present.
 Pioneer staff, support staff, including Commercial Counsel and General Counsel, were also in attendance.
 The Committee received a presentation, discussed the item, and approved the Chief Executive Officer, or designee, to submit a response to Liberty Utilities Energy Procurement Request for Proposals.

Pioneer Community Energy
Governance Committee
Committee Members
Alice Downdin Calvillo
Chair
Greg Janda
Vice Chair
City of Auburn
Alice Dowdin Calvillo
Sandra Amara, Alternate
City of Rocklin
Greg Janda
David Bass, Alternate
Nevada City
Gary Petersen
Daniela Fernandez, Alternate
City of Placerville
Ryan Carter
David Yarbrough, Alternate

SUMMARY REPORT
 The Governance Committee convened on October 6, 2026, with a quorum of members present.
 Pioneer staff and General Counsel were also in attendance.  The Committee discussed and provided direction to staff on items brought before the Board for the October 15th meeting.

Recommendations included amendments to the Bylaws, Joint Exercise of Powers Agreement, and related policies.
 The Committee also recommended the establishment of a Legislative & Regulatory Committee and Community Advocacy Committee.
 The Committee will convene again before the end of the year to discuss the CEO’s contract.

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 10/15/2026

PERSONNEL
Current Recruitments
Four offer letters were accepted for the Community Outreach Specialist positions with expected start dates in early November. The recruitment is still active with one open position to fill.

Interviews were conducted for the Chief Human Resources Officer position. I expect to close the recruitment before the end of the month.

DIABLO CANYON NUCLEAR POWER PLANT TOUR
Directors Carter and Pearl joined me for a tour of the Diablo Canyon Power Plant. The staff were phenomenal and the site was impressive. Staff will coordinate with the Plant for additional tours in 2027.

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) The following agreements have been conducted by the Chief Executive Officer, consistent with the authority delegated by the Board:
 10/1/26 Agreement with PaulosAnalysis for the Residential and Commercial Incentive Finder Tools program in the amount of $75,000 over a two-year term.

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:

QUARTERLY STRATEGIC PLAN PROGESS REPORT
Please see Attachment 5 for the quarterly progress report. I am happy to report that in year two of the three-year plan, there are no tasks that are critical status with most of the objectives either completed or near completion.

PRESENTATIONS AND RELEVANT MEETINGS ATTENDED BY THE CHIEF EXECUTIVE OFFICER

1. Participated in monthly CalCCA Board and Committee meetings including offsite Two-Day Retreat

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

3. Attended charity event for Feeding the Foothills

4. Attended charity event for Eskaton as a guest of Greater Sacramento Economic Council

CONGRATULATIONS TO GINA
Gina Stassi-Vanacore, Director of Communications, was selected by CalCCA as a 2026 CalCCA All-Star for her outstanding contributions to the CalCCA Annual Conference.

Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
California Choice Energy Authority 9/23/2026 Buy Resource Adequacy - Flex 12/1/2026 12/31/2026 $ 33,000 Agenda Item: IV-B Agenda Date: 10/15/2026

LOOMIS EVENT
Pioneer had a booth staffed for the Town of Loomis’s annual Fruit Shed event. (Young lady enjoying Pioneer promotional items)

QUARTERLY SPONSORSHIP ACTIVITY REPORT
The table below shows the sponsorship activity for the first quarter of the fiscal year:

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report

5. Quarterly Strategic Plan Progress Report
Event Date Member Community Vendor Special Event Amount 7/2, 7/9, 2026 Grass Valley Grass Valley Downtown Association Thursday Night Markets $400 7/4/2026 Grass Valley Grass Valley Downtown Association Annual 4th of July Celebration 1,500 7/25, 8/15, 9/26,
2026 Colfax Historic Colfax Downtown Association Live in Colfax - A Summer Concert Series 600 7/3/2026 Colfax Colfax 3rd of July Colfax Annual 3rd of July 1,500 7/4/2026 Auburn Auburn Chamber of Commerce Auburn's Family Fourth 2026 1,000 7/4/2026 Lincoln Lincoln Area Chamber of Commerce Lincoln 4th of July 1,000 7/4/2026 Nevada City Nevada City Chamber of Commerce 4th of July Parade 1,000 7/18/2026 GRV/NVC Sierra Nevada Memorial Hospital Foundation Starry, Starry Night 2,500 8/12-16, 2026 Nevada County Nevada County Fairgrounds Nevada County Fair 2,050 8/29/2026 Lincoln Lincoln Area Chamber of Commerce 2026 Lincoln Wings and Wheels 1,500 9/10-13, 2026 Auburn Gold Country Fair Gold Country Fair 1,000 9/13/2026 Rocklin Rocklin Public Safety Foundation Patriot Day 1,000 9/24/2026 Loomis Loomis Basin Chamber of Commerce
Acres of Hope - Comedy in the Barn
Fundraiser 350
9/23-25, 2026 Statewide Rural County Representatives of California RCRC Annual Meeting 2,500 2026-27 GRV/NVC Community Foundation of Nevada County Wildfire/Disaster Preparedness – COAD 10,000 2026 (ongoing) Placerville City of Placerville Bell Tower Renovation 7,500 TOTAL $35,400
Sponsorship Activity thru September 30, 2026
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 10-2-26

BOARD OF

DIRECTORS
OCTOBER 15, 2026

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

SPECIAL & REGULAR

MEETING
2:30 PM
(Post Agenda: November 6)
DECEMBER 17, 2026

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

IN THE FUTURE
Special Meeting Closed Session-Labor (CEO contract) JAN>JUL New Member orientation/ workshops
Regular Meeting JAN Regular Meeting & Public Hearing
(2027 Rates)
Consent 1a Minutes for Approval-SEP 17, 2026 Minutes for Approval-OCT 15, 2026 Minutes for Approval-NOV 12, 2026 DEC/JAN RES Amendment No. 7 to the Employment Agreement for CEO Donald
Eckert (General Counsel)
1b Receive Draft Financials JUL-AUG 2026
(Koehn)
If no AUG Financial Reports, prepare Notice
> agenda packet (Koehn)
Receive Draft Financials SEP-OCT 2026
(Koehn)
DEC/JAN RES Contract Amendment with
PAE Consulting Engineers (Kang)
1c RES Sagent Contract Amendment
(Stassi-Vanacore)
RES Granicus contract extension (Stassi-Vanacore)
1d RES Policy Amendments- (3) IT (Koehn) RES Agreement for Core Program (Kang)
1e RES Amendment No. 3 with Greenlite
Lighting Corp. for LED Discount Lighting
Program (Kang)
RES Calpine contract amendment
(action- Stassi-Vanacore)
Presentation

2a-Calpine Grant Award Presentation
guest: Calpine (Matt)
2b-2026 End of Legislative & Regulatory
Session Successes
guest: NPA-Cassandra
2c-Presentation
guest: Barry Broome
2a-RES Recognition of Board Members
leaving office
Regular 2
Proposed Administrative Changes to the JPA & Approve 30-Day Notice [DEC 17 vote] (action-Eckert)
Proposed Expansion JPA Amendment &
Approve 30-Day Notice
[DEC 17 vote] (action-Eckert)
RES JPA Amendments No. 9 -
Administrative Changes (action-Eckert) -PCIA Hedging/Reserves (Eckert)-Economic Development Rates (Eckert) -RES Large Load Policy (Kang)
3 RES approving Proposed Administrative
Changes to Bylaws [Amendment No. 8]
(action-Eckert)
RES JPA Amendment No. 10 - Expansion
(action-Eckert)
-FY 28-30 Strategic Plan (Eckert) JAN State of the Power Markets (Kang) 4 RES Approving Code of Conduct Policy
for the Board of Directors (action- Eckert)
Review of Unaudited Financials ending
June 2026 (discussion-Koehn)
JAN (PH) RES Authorizing 2027 Rate
Adjustment effective [date] (Eckert)
5 Update and RES Expansion into Liberty
Utilities Territory (action-Eckert)
Programs Year in Review
(discussion-Kang)
JAN RES Approving 2027 Meeting
Schedule-Governing Board (Eckert)
6 Expansion Outreach
(discussion- Stassi-Vanacore)
JAN RES Approving 2027 Meeting
Schedules-Committees (Eckert)
JAN RES Establishing Ad Hoc EPRC &
Appointing Members for 2027 (Eckert)
General Function II Chief Executive Officer’s Report
REG Reports:

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

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

Leg/Reg; Communications; Programs;
Chief Executive Officer’s Report
QTRLY Updates requested by the Board
JAN – APR – JULY – OCT
 Strategic Plan Objectives
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 10-2-26
AUDIT/FINANCE COMMITTEE TO BE SCHEDULED – DEC/JAN
in-person & remote locations IN THE FUTURE
Gary Petersen, Chair
Richard Pearl, Vice Chair
Greg Janda
Sean Lomen
David Ring
o July 13, 2026 Minutes
o Review Financial Audit
o Review 2027 Rates
o (2027) Select Officers
GOVERNANCE COMMITTEE TO BE SCHEDULED – PRIOR TO NOV 12 BOARD in-person & remote locations IN THE FUTURE
Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o Closed Session-Labor (CEO contract)
o October 6, 2026 Minutes
o [OCT/NOV] 2026 Meeting Minutes

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE

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

EXPANSION

AD HOC COMMITTEE

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

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

Attachment: Legislative and Regulatory Update
Date: 10/15/2026
Legislative Affairs
The 2026 legislative session ended on August 31, 2026, and the Governor signed or vetoed bills by September 30, 2026. Pioneer’s biomass bill to create the FOREST Fund, AB 706 (Aguiar-Curry), was signed by the Governor and has now become law. This is a major win for Pioneer as the final bill has all the major provisions we originally wanted. Our focus will now turn to implementation of the bill.

The results of Pioneer’s priority bills are as follows:
• AB 706 (FOREST Fund) – Signed by Governor
• AB 1761 (PCIA Transparency) – Vetoed by Governor
• SB 1138 (RA Transactability) – Held in Appropriations (did not pass) • SB 886 (Transmission and Distribution for Data Centers) – Signed by Governor • AB 2383 (Energy Rate for Data Centers) – Signed by Governor • AB 2111 (Long-Term Transmission Planning) – Signed by Governor The 2027 legislative session will begin in January 2027, and legislators have until February to introduce bills.

Pioneer is working with CalCCA to develop legislation on the PCIA that could address some of the major barriers. These discussions are in early stages, so there are not yet details on bill ideas, but we will participate in the process to ensure our interests are represented.

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:........................................2 • California Climate Credit – R. 25-07-013:..................................................................................4 • Integrated Resource Planning (IRP) – R.20-05-003; R.25-06-019:...........................................5 • Renewables Portfolio Standard (RPS) – R.24-01-017; CEC OIR 21-RPS-02:..............................7 [Publish Date] Agenda Date: 10/15/2026

• Resource Adequacy (RA) – R.23-10-011; R.25-10-003: ............................................................8 • Large Loads (PG&E Rule 30) – A.24-11-007:.............................................................................9 • Demand Response – R.25-09-004: .......................................................................................... 12 • PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast: ......................... 13 o 2024 ERRA Compliance – A.25-02-013: ............................................................................... 15 o 2025 ERRA Compliance – A.26-02-019 ................................................................................ 15 o 2026 ERRA Forecast – A.25-05-011:.................................................................................... 16 o 2027 ERRA Forecast – A.26-05-007:.................................................................................... 16 • PG&E General Rate Case (GRC) Phase 1 – A.25-05-009: ......................................................... 17 • PG&E General Rate Case Phase 2 – A.24-09-014: ................................................................... 19 • Provider of Last Resort (POLR) – R.21-03-011: ...................................................................... 20 • CEC Load Management Standards (LMS) – CEC 21-OIR-03; 26-OIR-01; 23-LMS-01:............... 21 • Power Charge Indifference Adjustment (PCIA) – R.25-02-005: .............................................. 22 • Safety & Reliability OIR– R.24-05-023: ................................................................................... 26 • Disconnections – R.18-07-005: ............................................................................................... 28 • High-DER Future – R.21-06-017:............................................................................................. 29 • Distributed Energy Resources – R.22-11-013: ........................................................................ 31 • Distributed Energy Resource Interconnections (Rule 21) – R.25-08-004:............................... 32 • 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
[Publish Date] Agenda Date: 10/15/2026

i. The BioMAT program closed on the currently effective sunset date of December 31, 2025. The CPUC removed its proposed decision responding to Bioenergy Association of California’s (BAC’s) PfM requesting an extension of this sunset date from its January 15, 2026 voting meeting agenda, meaning the program has effectively ended without CPUC action.
ii. April 10, 2026 - The CPUC issued a new PD denying BAC’s PfM, requesting extension of the BioMAT program, which was originally filed in March 2025. The CPUC previously issued a PD in response to BAC’s PfM in September 2025, but the PD was ultimately withdrawn and never passed. The new PD does not address the substance of BAC’s PfM, nor address the comments that parties including the Joint CCAs filed in response, but instead primarily makes a procedural argument for why the PfM is denied.
iii. May 14, 2026 – The CPUC issued D. 26-05-008, denying BAC’s PfM requesting extension of the BioMAT program. The CPUC stated that based on procedural grounds, BAC’s PfM was not appropriately addressed within one year of the original decision, D.20-08-043, setting the BioMAT program sunset date. iv. May 26, 2026 – BAC filed an application for rehearing (AfR) of D. 26-05-008, stating that the CPUC’s procedural argument is legally erroneous. v. June 4, 2026 – Pioneer and Redwood Coast Energy Authority (RCEA), namely the “Joint CCAs” had an ex parte with Commissioners Harada and Reynolds’ offices to request for the issue of BioMAT extension to be considered in the current RPS rulemaking. Pioneer discussed our recent success in executing six BioMAT PPAs, demonstrating stakeholders’ continued interest in the BioMAT program and the need for the CPUC to consider reviving/ extending it.
vi. September 1, 2026 – Pioneer filed an application for compliance review of its administration of the BioMAT program. In the application and supporting testimony, Pioneer seeks to establish compliance with the CPUC’s prudent contract manager standard by describing how Pioneer deemed the six BioMAT program participation requests (PPRs) it received and power purchase agreements (PPAs) it executed eligible for the program.
vii. PG&E filed a response to our BioMAT application that supports the application and offers an alternative schedule to better fit with existing regulatory processes.

Pioneer will likely file a response on October 15, 2026 to state that we are supportive of PG&E’s proposed changes.
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 [Publish Date] Agenda Date: 10/15/2026

iv. PD Denying BAC PfM to Modify D.20-08-043 (September 18, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M580/K430/580430313.PDF • Ultimately withdrawn from the CPUC Voting Meeting agenda, and never passed v. Opening Comments of Joint CCAs (Pioneer and RCEA) on PD Allowing the BioMAT Program to Sunset (October 8, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M582/K487/582487980.PDF vi. D. 26-05-008 Denying BAC PfM to Modify D. 20-08-043 (May 14, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M606/K808/606808546.PD F
vii. BAC Application for Rehearing of D. 26-05-008 (May 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M607/K644/607644121.PDF f. Key Dates
i. October 15, 2026 file reply to PG&E’s response to our BioMAT application 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 – D. 26-03-013 was adopted, ordering the large electric IOUs to pause distribution of the 2026 residential climate credit, so the Commission can consider when the credits should be distributed.
iii. April 30, 2026 – D. 26-04-036 was adopted, requiring the large electric utilities to distribute the residential electric climate credits in August and September starting in [Publish Date] Agenda Date: 10/15/2026

2026, and the gas utilities to distribute the residential gas climate credits in February starting in 2027. The rationale for shifting the distribution timeline of the climate credits is to move it to the highest-bill months, typically occurring in summer, where the credits can have a greater impact on alleviating costs. e. Background Documents/ Key Decisions
i. Scoping Ruling (February 3, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M597/K166/597166396.PDF ii. Decision Pausing the 2026 Residential Climate Credits Distributed by the Large Electric Utilities (March 19, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M603/K306/603306591.PD F
iii. Decision Ordering Immediate Improvements to the CCC to Lower Electric and Gas Bills (May 1, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M605/K990/605990203.PD F
f. Key Dates
i. None.
g. Pioneer Lead: Chau Pham
• Integrated Resource Planning (IRP) – R.20-05-003; R.25-06-019:
a. Proceeding Overview
i. This proceeding acts as the venue for long-term procurement planning, primarily through procurement mandates and compliance evaluations of LSEs' individual IRP plans. Historically, the CPUC has issued procurement mandates, most notably the mid-term reliability (MTR) orders, specifying how much and what kind of resources LSEs are obligated to buy, to ensure the state's electricity supply is reliable, cost-effective, and on track to meet greenhouse gas (GHG) reduction goals. The CPUC is 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
[Publish Date] Agenda Date: 10/15/2026

i. June 23, 2026 – The CPUC issued a new, Reliable and Clean Procurement Program (RCPPP) proposal (Option 3), to be considered in addition to the previous two proposals that were issued in April 2025. Given the wide variety of comments received on the RCPPP proposals in 2025 which show parties have not been able to reach consensus on a RCPPP framework, the CPUC proposes a simpler RCPPP framework in this new ruling. This RCPPP proposal intends to keep the IRP/ RCPPP program distinct from the RA program, by continuing to use different capacity valuation methodologies for the respective programs. The primary purpose of this RCPPP proposal is to connect long-term transmission planning with procurement orders. Under the proposed framework, the adoption of transmission planning process (TPP) portfolios would form the procurement needs for 5 years out, with a requirement of 100% of an LSEs’ resource obligation being contracted in year 3 and 100% of the resources being online in year 5. LSEs’ procurement obligations would be based on their peak system load share, as indicated in the CEC Integrated Energy Policy Report (IEPR), with an additional 1% buffer on top to account for uncertainties and delays. The proposed program would begin in 2028 with the adoption of the TPP portfolio and procurement need for 2033, recurring in 2-year TPP cycles. In many ways, this proposal retains a similar structure to the previous mid-term reliability procurement orders that have come out of the IRP proceeding but with a more regular cadence/ timeline, whereas the previous two RCPPP proposals issued in 2025 contained more sweeping changes and reform to align the IRP, RA, and RPS program. Pioneer will work with CalCCA to provide comments on the new proposal. The CPUC has indicated the next step in the development of the RCPPP framework is a PD.
ii. August 14, 2026 - CalCCA and 40+ parties filed comments on the RCPPP Option 3 proposal. CalCCA urged the CPUC to reject the RCPPP Option 3 proposal because tying procurement requirements to TPP portfolios would likely risk distorting the market, shifting power to sellers, and increasing ratepayer costs. Instead, CalCCA recommended the CPUC adopt the RCPPP Option 1 proposal which allows for procurement of new and existing resources, coupled with a Clean Energy Standard (CES) framework that ensures sufficient procurement of clean resources. If the CPUC insists on adopting a RCPPP framework that only allows for procurement of new resources, CalCCA recommended they adopt Option 2 with modifications to the need determination and need allocation methodologies, and compliance and enforcement components, to ensure proper flexibility.
iii. September 2, 2026 - CalCCA filed reply comments on the RCPPP Option 3 proposal.

CalCCA aligned with CAISO, SCE, CalAdvocates, and AReM on why Option 3 should be rejected, as parties find the framework to be too prescriptive, not reflective of market conditions, not aligned with the RA and RPS programs, and lacking pathways for procurement of long-lead time resources. CalCCA also urged the CPUC to reject party recommendations for prescriptive resource or attribute-specific procurement requirements, use of a central procurement entity, or a buffer. e. Background Documents/ Key Decisions
i. ALJ Ruling Seeking Comments on Reliable and Clean Power Procurement Program (RCPPP) Staff Proposal (April 29, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M565/K140/565140721.PDF ii. ALJ Ruling Seeking Comments on Proposed 2026-2027 Transmission Planning Process (TPP) Portfolios and Need for Additional Near-Term Reliability Procurement (September 30, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M582/K082/582082526.PDF [Publish Date] Agenda Date: 10/15/2026

iii. R.25-06-019 Scoping Memo and Ruling (October 28, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M585/K485/585485746.PDF iv. Proposed Decision Requiring 2029-2032 Electric Resource Procurement and Transmitting 2026-2027 Transmission Planning Process (TPP) Portfolios (January 14, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M595/K083/595083681.PDF v. ALJ Ruling Setting New Requirements for Individual Integrated Resource Plans Due June 1, 2026 (January 16, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M595/K085/595085015.PDF vi. Revised Decision Requiring 2029-2032 Electric Resource Procurement and Transmitting 2026-2027 TPP Portfolios (February 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M600/K398/600398976.PD F
vii. ALJ Ruling Granting Joint Request for Extension of LSEs’ IRP Filings (March 9, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M601/K895/601895997.PDF viii. ALJ Ruling Seeking Comments on Additional Proposal for RCPPP (June 23, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M609/K223/609223925.PDF f. Key Dates
g. Pioneer Lead: Chau Pham
• Renewables Portfolio Standard (RPS) – R.24-01-017; CEC OIR 21-RPS-02:
a. Proceeding Overview
i. This proceeding acts as the venue for the CPUC’s implementation and administration of the state's RPS program, which aims to achieve 60% renewable energy by 2030, and 100% carbon-free by 2045.
b. Potential Impact on Pioneer
i. Pioneer is required to comply with the state’s RPS goals. All retail sellers must submit an annual preliminary RPS compliance report each year on August 1, to be evaluated by the CPUC in this proceeding. RPS compliance is evaluated in multi-year periods; we are currently in compliance period 5 (2025-2027). The next RPS target is 52% by 2027. It is Pioneer's priority to ensure RPS rules maintain the highest compliance flexibility possible (allowing for banked RECs, etc) to allow for cost-effective procurement. c. Key Issues
i. Ensure any RPS rules maintain compliance flexibility to the highest degree possible ii. Advocate for fair inclusion of biomass resources in the RPS program and guidelines (this may also take place in the CEC RPS proceeding), including the ongoing administration of the BioMAT program
d. Status Update
i. March 27, 2026 - An ALJ ruling was issued identifying issues and schedule of review for 2026 RPS Procurement Plans. Minor revisions were made to the RPS Plan requirements. The annual draft RPS Plan will be due June 12, 2026. ii. May 7, 2025 - The CPUC approved Pioneer's Final 2025 RPS Procurement Plan. [Publish Date] Agenda Date: 10/15/2026

iii. August 21, 2026 – Pioneer filed its Final Compliance Period 4 (2021-2024) Compliance Report, providing data that showed Pioneer had fulfilled its RPS requirements for Period 4.
e. Background Documents/ Key Decisions
i. Pioneer Community Energy Draft 2025 RPS Procurement Plan (June 30, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M571/K990/571990166.PDF ii. PD on 2025 RPS Procurement Plans (November 14, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M587/K328/587328286.PDF iii. Pioneer Community Energy Final 2025 RPS Procurement Plan (January 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M596/K418/596418446.PDF f. Key Dates
g. Pioneer Lead: Chau Pham
• Resource Adequacy (RA) – R.23-10-011; R.25-10-003:
a. Proceeding Overview
i. This proceeding aims to ensure the reliability of CA's electricity supply by requiring that LSEs procure sufficient resources to meet their load plus a planning reserve margin (PRM). The RA program recently implemented a slice of day (SOD) framework, ensuring LSEs are compliant every hour of the worst day of the month. b. Potential Impact on Pioneer
i. Pioneer is required to comply with RA procurement requirements and filings. Annual (year ahead) filings are due on October 31 each year and monthly (month ahead) filings are due 45 calendar days prior to the compliance month. Furthermore, RA requirements have significant impacts on the procurement market which Pioneer operates in. Therefore, Pioneer advocates for RA procurement requirements and policies that minimize adverse effects on the RA market. c. Key Issues
i. Advocate for refinements in the RA program that minimize RA requirements (based on robust modeling) to ensure adequate market availability and guard against RA price volatility
ii. Advocate for simplifying RA showings/ compliance requirements to the greatest extent possible
d. Status Update
i. August 25, 2026 – An amended Scoping Ruling was issued to set the topics and schedule for Track 2, which includes:
• Adoption of 2028-2030 local and flexible capacity requirements • Planning reserve margin (PRM) for 2028-2029
• Unforced capacity (UCAP) implementation
• Accreditation of long duration energy storage (LDES) open-loop pumped storage hydropower (PSH), solar, wind, and non-dispatchable resources • Value of energy only (EO) resources towards charging sufficiency • RA penalty structure
e. Background Documents/ Key Decisions
[Publish Date] Agenda Date: 10/15/2026

i. Issuance of OIR 25-10-003 (October 15, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M583/K934/583934825.PD F
ii. Scoping Ruling (December 12, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M590/K884/590884355.PDF iii. ALJ Ruling on ED’s Transactability Report (February 23, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=600063407 iv. Revised Track 1 PD (June 30, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?docformat=ALL&docid=609912508 f. Key Dates
i. Fall 2026 – Issuance of Track 2 Scoping Memo and Schedule ii. Fall 2026 – Consideration of LOLE Studies and PRM Proposals iii. Winter 2027 – Consideration of Other Track 2 Proposals iv. Summer 2027 – Proposed Decision on Track 2
g. Pioneer Lead: Chau Pham
• Large Loads (PG&E Rule 30) – A.24-11-007:
a. Proceeding Overview
i. This is PG&E's proposed tariff to address the interconnection of non-residential customers requesting retail electric service at transmission-level voltages between 50 kilovolts (kV) and 230 kV, otherwise known as transmission-level customers.

These large loads are becoming more significant as data centers propagate. PG&E’s current electric rules are intended for distribution-level interconnections. As such, when a customer applies for transmission-level retail electric service, PG&E and the customer negotiate unique interconnection terms, and PG&E is required to make an “exceptional case” filing with the Commission for approval of the negotiated agreement. PG&E states that creating a uniform tariff (proposed Electric Rule 30) will streamline both the negotiation process and the approval process, resulting in faster interconnection timeline.
b. Potential Impact on Pioneer
i. New large loads, such as data centers, located in Pioneer’s service territory present both challenges and opportunities to Pioneer. If Pioneer is going to provide generation service to these customers, it needs visibility into which applications are expected to come online in its service territory (if any) for procurement planning purposes. It will also need to have a commitment from these customers far enough in advance for Pioneer to procure adequate resources to meet any compliance deadlines for serving these new loads.
c. Key Issues
i. Ensure Pioneer obtains information regarding new large loads when that information is obtained by the IOU, either before or at the time of a customer request for interconnection with the IOU’s transmission or distribution system; ii. Ensure the ability of Pioneer to adequately prepare to serve customers through timely access to information regarding large loads; and [Publish Date] Agenda Date: 10/15/2026

iii. Support customer choice of generation providers through ensuring IOUs and CCAs compete on a level playing field.
d. Status Update
i. May 8, 2026 – PG&E requested CPUC approval of a partial settlement agreement between itself, CalCCA, Cal Advocates, and Sierra Club. The relevant terms of the settlement agreement are as follows:
• Information Sharing (Under New NDA)
a. Interconnection Inquiries:
i. PG&E shall share the same information regarding all
transmission-level retail interconnection inquiries that it includes in submissions provided to the CEC at or about the same time that it provides this information to the CEC
b. Post-Application and Pre-Energization
i. Quarterly Reports regarding retail electric customers seeking to interconnect that have submitted an application for
transmission-level service
c. Post Energization
i. Annual Reports regarding facilities that have been
interconnected at the transmission-level and have been
energized
• Non-Disclosure Agreement
a. For affected CCAs, each CCA will execute a new NDA which will govern information sharing regarding interconnections for transmission-level retail electric service under Electric Rule 30 or any other PG&E tariff rule
• Coordination of Service
a. CCAs are the default providers of generation service for new customers in their service areas
b. Customers will be considered enrolled with the default provider upon the customer’s execution of an interconnection agreement or eight months prior to the energization date identified in the Preliminary Engineering Study (PES) Report for the customer’s facility, whichever is earlier.
i. PG&E will provide an affected CCA notice of the energization date identified in the PES report within 3 business days of the customer’s signature of the PES report.
ii. PG&E will also provide an affected CCA notice of the execution of an interconnection agreement within 3 business days
c. Under California Public Utilities Code Section 366.2(c)(13), a transmission-level customer has a statutory 60-day opt-out period after enrollment to opt out of default CCA generation service. d. Within 3 business days following the 60-day opt-out period, the entity selected as the service provider shall confirm that it will provide [Publish Date] Agenda Date: 10/15/2026

generation service to the customer in writing to the other entity that will not be providing generation service to that customer. e. After the opt-out period, the customer cannot switch providers until at least one year after energization and after giving 18 months’ notice. ii. August 7, 2026 – The CPUC issued a ruling requesting comments related to FERC’s show cause order to CAISO and the Participating Transmission Owners (PTOs) in order to develop the record of the proceeding. The show cause order, issued on June 18, 2026, asks CAISO and the PTOs to explain how their tariffs support interconnection of large loads, or alternatively, to propose changes. FERC’s order aims to advance the goals of the Secretary of Energy’s efforts to expedite the integration of large loads onto the transmission system. iii. September 9, 2026 – CalCCA submitted comments requesting that the Commission adopt the Partial Settlement proposed by PG&E, Cal Advocates, CalCCA, and Sierra Club, which will improve the ability to forecast large loads consistent with the goals of the FERC Order. The partial settlement will require IOUs to share information about any new transmission-interconnected load with affected CCAs. e. Background Documents/ Key Decisions
i. PG&E Application for Approval of Electric Rule No. 30 for Transmission-Level Retail Electric Service (Nov. 21, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=547155949 ii. Joint CCA Response to Application (Dec. 23, 2024):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M549/K797/549797836.PDF iii. PG&E Motion for Interim Implementation of Rule 30 (Jan. 24, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=555445559 iv. Joint CCA Response to Motion for Interim Implementation (Feb. 10, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=556602084 v. Scoping Ruling (March 11, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=558423070 vi. D.25-07-039, partly granting PG&E’s Motion for Interim Implementation of Rule 30 (July 28, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M574/K875/574875643.PD F
vii. Order Instituting Proceeding Under Section 206 of the Federal Power Act (June 18, 2026): https://www.ferc.gov/media/e-10-el26-71-000
f. Key Dates
i. March 11, 2026 – Scoping Memo Issued
ii. May 8, 2026 – Opening Briefs on additional cost allocation questions iii. May 22, 2026 - Reply Briefs on all issues
iv. August 7, 2026 - ALJ Ruling Seeking Comments on Proceeding Status v. Q4 2026 – Proposed Decision
vi. Q1 2027 – CPUC Decision
g. Pioneer Lead: Braden Henderson
[Publish Date] Agenda Date: 10/15/2026

• 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 the CPCU could address in this proceeding include dual participation of DR resources among different programs, adjustments to the DR guiding principles, and integration into other systems and processes, including the resource adequacy slice of day (RA SOD) and the CAISO market.
b. Potential Impact on Pioneer
i. Under the law, demand response and energy efficiency are the first resources that electric corporations use to meet their needs, so there is a statutory mandate to generally include it in the California resource mix. There could also be a specific impact on Pioneer's programs that fall under the umbrella of demand response, including the PowerShift Rewards program.
c. Key Issues
i. Pursue systems and processes that support timely and consistent Pioneer access to customer interval data, both billing-quality and non-billing-quality ii. Ensure Pioneer customers have equitable access to demand response resources iii. Ensure new policies or programs do not encroach on Pioneer rate and program autonomy
d. Status Update
i. July 7, 2026 - ALJ ruled to eliminate the testimony, evidentiary hearing, and briefs from the schedule as no disputed material facts or questions of law regarding the Bridge Year Funding Issue emerged from the comment and reply comment periods.
ii. September 25, 2026 – The CPUC released a Proposed Decision authorizing bridge funding for the 2028-2029 DR programs operated by the IOUs while the Commission considers DR reforms. The Emergency Load Reduction Program (ELRP) will be limited to subgroups A.4 (Virtual Power Plant Aggregators) and A.5 (Electric Vehicle and Vehicle-Grid Integration Aggregators) for PG&E and SCE. e. Background Documents/ Key Decisions
i. Order Instituting Rulemaking (Sept. 18, 2025) (including the Demand Response Guiding Principles Staff Report):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M582/K072/582072320.PD F
ii. Scoping Memo and Ruling (Feb. 12, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=599038857 f. Key Dates
i. April 30, 2026 – Opening Comments on Bridge Funding Staff Proposal Ruling ii. May 21, 2026 – Reply Comments on Bridge Funding Staff Proposal Ruling iii. September 25, 2026 – Proposed Decision on IOU DR Bridge Funding [Publish Date] Agenda Date: 10/15/2026

iv. Q4 2026 – Proposed Decision on all other issues
g. Pioneer Lead: Braden Henderson
• California Advanced Electric Rate Design– R.26-04-009:
a. Proceeding Overview
i. This proceeding is to modernize electric rate design to better reflect cost causation, improve affordability, and support efficient grid use amid rising costs and changing system conditions. The proceeding will evaluate reforms to residential and non-residential rate structures, including time-of-use periods, fixed and demand charges, and marginal cost methodologies, to ensure rates align with current grid cost drivers and promote equitable cost allocation across customers. ii. It responds to increasing affordability pressures driven by wildfire-related costs and rapid load growth, while also advancing prior work from Rulemaking 22-07-005 and implementing statutory requirements under Assembly Bill 2109 and Senate Bill 57.

The rulemaking will further consider rate design solutions for large-load customers such as data centers, and support electrification and greenhouse gas reduction goals.
iii. This multi-track proceeding covers various topics related to developing new rate structures for an advanced energy system. The four-track proceeding includes:
• Track 1: Data Center Tariffs and Customer Protections • Track 2: Residential Rate Modernization
• Track 3: Nonresidential Rate Modernization
• Track 4: Dynamic Rates, Framework for Marginal Costs, and Framework for Transmission Revenue Requirements
b. Potential Impact on Pioneer
i. Data center tariff development is an important topic to follow as Pioneer will be subject to laws flowing down from AB 2383 language applicable to Load Serving Entities.
ii. While Pioneer’s board has autonomy to set its own rates, development of new IOU TOU rates is an important item for Pioneer to follow. Pioneer mirrors the IOU TOU structure to ensure customer bills are not complicated by having different TOU pricing signals.
iii. Dynamic rates have been in testing through pilot programs. Pioneer has participated by offering HFP in partnership with PG&E to our unbundled customers. Long-term implementation is a critical concept that, if it is to become more widespread for Pioneer’s customer base, needs to be done equitably and accurately reflect cost causation principles.
c. Key Issues
i. Senate Bill 57 (Padilla) requires the Commission to provide an assessment by January 1, 2027, on the potential cost impacts from new, large transmission-connected loads from data centers on electrical corporations and their customers. In coordination with the Senate Bill 57 assessment, this proceeding will consider rate design issues for data centers and other large load customers. ii. Current time-of-use rates may not accurately reflect low-cost periods both seasonally and on an hourly basis. A reexamination of time-of-use rate structures, including the pricing differentials between low- and high-cost periods, will support [Publish Date] Agenda Date: 10/15/2026

rate design updated to better reflect current costs and support customer behavior.

The Commission aims to evaluate both TOU rates and dynamic rates. d. Background Documents/ Key Decisions
i. R.26-04-009 Order Instituting Rulemaking (April 10, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M604/K677/604677976.PD F
ii. SB 57 – Electrical Corporations: Data Centers: Report (October 11, 2025):
https://leginfo.legislature.ca.gov/faces/billNavClient.xhtml?bill_id=202520260SB57 iii. AB 2109 - Electricity: Surcharge Exemption: Industrial Process Heat Recovery (September 27, 2024):
https://calmatters.digitaldemocracy.org/bills/ca_202320240ab2109 iv. SB 886: California Technology Innovation and Ratepayer Protection Act (September 21, 2026): https://calmatters.digitaldemocracy.org/bills/ca_202520260sb886 v. AB 2383: Electricity: data centers (September 21, 2026):
https://calmatters.digitaldemocracy.org/bills/ca_202520260ab2383 e. Status Update
i. September 22, 2026 - The Commission released the initial scoping memo for this proceeding. That will cover, but is not limited to, data center tariffs, TOU rate structures, and dynamic rate frameworks. The scope of this proceeding is anticipated to be related to other proceedings, including High DER, Demand Response, Rule 30, various IOU GRCs, and the CEC’s LMS. f. Key Dates
i. Track 1 Proposed Decision on Data Centers – Q2 2027
ii. Track 2 Proposed Decision on Residential Rates – Q3 2027 iii. Track 3 Proposed Decision on Commercial Rates – Q1 2028 iv. Track 4 Proposed Decision on Dynamic Rates – TBD
g. Pioneer Lead: Braden Henderson
• PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast:
a. Proceedings Overview
i. Generally, the ERRA Compliance proceedings review IOU accounting for its generation costs in the previous year, which includes accounting related to the Power Charge Indifference Adjustment (PCIA) and Portfolio Allocation Balancing Account (PABA). The purpose is to ensure accuracy and compliance with legal requirements, including CPUC rules and decisions.
b. Potential Impact on Pioneer
i. Although typically not as contentious as the ERRA Forecast proceedings, PG&E's applications in the ERRA Compliance proceedings often include errors or non-compliant activities which, when corrected, result in a credit to unbundled customers via the PCIA, which is incorporated in the ERRA Forecast proceedings. This proceeding is also an opportunity to review PG&E's activities related to its PCIA resources, although transparency is always a challenge.
[Publish Date] Agenda Date: 10/15/2026

ii. This is the proceeding in which the PCIA revenue requirement for the following rate year (i.e., 2026 in this proceeding) is established. The parties and the CPUC arrive at the revenue requirement by reducing the costs of PCIA resources by their value and adding any over- or under-collection of PCIA from the current rate year (i.e., 2025 in this proceeding). That revenue requirement is then assigned to customer vintages based on the resource vintage to develop PCIA rates. Given all of Pioneer's customers pay PCIA rates, Pioneer's goal is to ensure that its customers are only paying the costs that we actually incurred on their behalf and receiving the full value of the PCIA resources.
o 2024 ERRA Compliance – A.25-02-013:
a. Key Pioneer Issues
i. Ensure qualifying facilities and contracts were prudently administered and managed, entries in balancing and memorandum accounts were recorded appropriately, correctly, and in compliance with CPUC decisions, and whether recovery for 2024 record year costs is reasonable.
b. Status Update
i. No updates.
c. Background Documents/ Key Decisions
i. PG&E Application (February 28, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=557607577 ii. CalCCA Protest (April 4, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=561478629 iii. Scoping Ruling (May 2, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=565140242 d. Key Dates
i. Intervenors' Testimony - September 15, 2025
ii. Rebuttal Testimony - October 24, 2025
iii. Evidentiary Hearing - December 2, 2025
iv. Opening Briefs - January 5, 2026
v. Reply Briefs - February 6, 2026
vi. Proposed Decision - no later than 90 days after reply briefs vii. Final Decision - no sooner than 30 days after Proposed Decision e. Pioneer Lead: Chau Pham
o 2025 ERRA Compliance – A.26-02-019
a. Key Pioneer Issues
i. Ensure qualifying facilities and contracts were prudently administered and managed, entries in balancing and memorandum accounts were recorded appropriately, correctly, and in compliance with CPUC decisions, and whether recovery for 2024 record year costs is reasonable.
b. Status Update
[Publish Date] Agenda Date: 10/15/2026

i. CalCCA reviewed PG&E’s ERRA filing and identified only minor changes, which PG&E has agreed to make. CalCCA therefore will not request testimony on any issues. c. Background Documents/ Key Decisions
i. PG&E Application (February 27, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M601/K158/601158608.PDF ii. CalCCA Protest (April 2, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M604/K016/604016143.PDF d. Key Dates
e. Pioneer Lead: Jon Hart
o 2026 ERRA Forecast – A.25-05-011:
a. Key Pioneer Issues
i. Ensure accuracy of forecast account balances and rates, cost calculations in workpapers, and calculation of Market Price Benchmarks (MPBs) ii. Ensure costs are attributed to the proper PCIA vintage iii. Ensure costs are attributed properly between bundled and unbundled customers iv. Ensure IOU specific proposals are appropriate for an ERRA Forecast proceeding b. Status Update
i. No updates.
c. Background Documents/ Key Decisions
i. PG&E Application (May 15, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566243428 ii. Scoping Ruling (June 20, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=574962660 iii. CalCCA Brief (October 24, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=585485747 d. Key Dates
i. A final decision in this proceeding is anticipated in December 2025, with implementation into rates beginning January 1, 2026.
e. Pioneer Lead: Chau Pham
o 2027 ERRA Forecast – A.26-05-007:
a. Key Pioneer Issues
i. Ensure accuracy of forecast account balances and rates, cost calculations in workpapers, and calculation of Market Price Benchmarks (MPBs) ii. Ensure costs are attributed to the proper PCIA vintage iii. Ensure costs are attributed properly between bundled and unbundled customers iv. Ensure IOU specific proposals are appropriate for an ERRA Forecast proceeding b. Status Update
i. May 15, 2026 - PG&E filed its 2027 ERRA Forecast application. The initial application forecasts that PCIA rates for unbundled customers will decrease, but the rate is [Publish Date] Agenda Date: 10/15/2026

expected to increase from now until the October update and annual true-up because PG&E used outdated values (2026 GRC revenue requirement, 2026 RA/RPS MPBs).

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

The testimony requests that PG&E revise its implementation of slice-of-day accounting as part of resource adequacy; PG&E value pre-2019 banked RECs; and that PG&E provide accurate forecasting for data centers. Currently, PG&E is forecasting large amounts of data centers coming online, which would drive up PCIA rates. It is unlikely that all of this load will materialize, so we want the forecast to be as accurate as possible so our PCIA rates are not impacted.
c. Background Documents/ Key Decisions
i. PG&E Application (May 15, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566243428 d. Key Dates
i. October 16, 2026 – PG&E update to forecast
ii. November 2026 – Proposed Decision
iii. December 17, 2026 – Final Decision
e. Pioneer Lead: Jon Hart
• PG&E General Rate Case (GRC) Phase 1 – A.25-05-009:
a. Proceeding Overview
i. In four-year cycles, IOUs submit GRC applications for authority to adjust rates and charges for electric and gas service based on a future test year (TY). The revenue requirements include electric and gas distribution system costs, administrative expenses, and customer service costs.
ii. In GRC Phase 1, the CPUC establishes the IOU's overall revenue requirement, which it later allocates in rates to different customer classes in 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. This proceeding will establish the costs of PG&E's Power Charge Indifference Adjustment (PCIA) generation resources and later recover them 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
[Publish Date] Agenda Date: 10/15/2026

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 PCIA cost recovery to reflect 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. April 27 – May 6, 2026 – CalCCA is participating in Evidentiary Hearings. CalCCA’s witness Ryan Matley is scheduled to be cross-examined on May 13, 2026. CalCCA’s cross-examination of PG&E’s witnesses will focus on hydro facility costs, proposed investments, and the correct vintaging of those hydro investments. PG&E has hydro assets on the books that have not been used, as well as new investments that may require re-vintaging.
e. Background Documents/ Key Decisions
i. PG&E Phase 1 2027 Application (May 15, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566363587 ii. PG&E Phase 1 2027 Scoping Ruling (July 31, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=575112973 f. Key Dates
i. Intervenors’ testimony - February 13, 2026
ii. Rebuttal testimony - March 31, 2026
iii. Case Management Conference
iv. Statement and Motions for Settlement - April 13, 2026 v. Evidentiary hearings - Starting April 27, 2026
vi. Opening briefs - June 19, 2026
vii. Reply briefs - July 10, 2026
viii. Proposed decision - March 2027
ix. Commission decision May - 2027
g. Pioneer Lead: Jon Hart
[Publish Date] Agenda Date: 10/15/2026

• 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. GRC Phase 2 focuses on designing 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 potentially impact 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, CCAs will need to fund such customizations. If CCAs want to use a different generation marginal RTP, they may contract with another entity to develop that price and calculate their unbundled customers’ generation bill. c. Key Issues
i. Ensure that CCAs have access to data needed to implement dynamic rates for any CCA that chooses to do so and ensure that PG&E's implementation of dynamic rates does not 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 [Publish Date] Agenda Date: 10/15/2026

service in 2026, using up-to-date data on PG&E’s processing times and labor costs; and (2) shortly after PG&E’s final implementation of its Billing Modernization Initiative (BMI) project, submitting testimony in its next GRC application regarding its actual costs as the POLR to process a customer’s voluntary return to bundled service, using up-to-date data on PG&E’s processing times and labor costs
e. Background Documents/ Key Decisions
i. PG&E Phase 2 2023 Application (Sept. 30, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=541493803 ii. PG&E Phase 2 2023 Scoping Ruling (Mar. 21, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=560273042 f. Key Dates
i. Cal Advocates Testimony -January 9, 2026
ii. Intervenors' Testimony – March 9, 2026
iii. Rebuttal Testimony – July 10, 2026
iv. Hearing - August 2026
v. Opening Briefs - Four weeks after Hearing
vi. Reply Briefs - Three weeks after Opening Briefs
vii. Proposed Decision - No later than 90 days after Reply Briefs viii. Final Decision - No sooner than 30 days after Proposed Decision g. Pioneer Lead: Jon Hart
• Provider of Last Resort (POLR) – R.21-03-011:
a. Proceeding Overview
i. Track 1 of the POLR proceeding determines/updates the methodology for the financial security requirement (FSR) that CCAs must post to ensure the IOUs (Current POLRs) have the capital to serve customers in an emergency mass return.

Track 2 of the proceeding gauged interest from any LSEs/IOUs 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 on any changes to 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
[Publish Date] Agenda Date: 10/15/2026

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 a lack of substantial interest from LSEs in transferring the POLR role.
g. Pioneer Lead: Chau Pham
• CEC Load Management Standards (LMS) – CEC 21-OIR-03; 26-OIR-01; 23-LMS-01:
a. Proceeding Overview
i. Docket 23-LMS-01 implements the CEC’s LMS (Calif. Code of Regulations, Title 20, sections 1621-1625), which include (among other mandates) requirements for CCAs to develop dynamic pricing by 2027. The objective of the LMS is to increase statewide demand flexibility through the development of hourly locational marginal cost-based rates. The rates will be entered into a statewide database – the MIDAS – and automation service providers will access customers’ rate information through a “Single Statewide Tool” created jointly by the IOUs, CCAs, and POUs. The statewide system of granular time- and location-dependent signals is 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 consideration of 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 [Publish Date] Agenda Date: 10/15/2026

ii. in accordance with the regulations
iii. Ensure that the CEC respects CCA autonomy in setting their own rates iv. Ensure Pioneer maintains compliance with CEC mandates and requirements d. Status Update
i. April 9, 2026 – The CEC issued an Order Instituting Rulemaking to evaluate improvements to implementation of the LMS and expand participation among ratepayers and third-party service providers.
e. Background Documents/ Key Decisions
i. Load Management Standards: https://www.energy.ca.gov/programs-and-topics/topics/load-flexibility/load-management-standards ii. Pioneer Revised Load Management Standard Plan:
https://efiling.energy.ca.gov/GetDocument.aspx?tn=266073&DocumentContentId= 103090
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: The Energy Commission will address Pioneer's Revised LMS Plan at its Business Meeting.
iii. May 8, 2026: Develop and submit to the CEC, in conjunction with the other obligated utilities, a single statewide standard tool for authorized rate data access by third parties along with the terms and conditions for use of the tool. Upon CEC approval, the tool will be live and obligated LSEs must maintain and improve the tool iv. One year after compliance plan approval (December 8, 2026) and annually 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 to the Plan to the Board if there is a material change.
g. Pioneer Lead: Braden Henderson
• Power Charge Indifference Adjustment (PCIA) – R.25-02-005:
a. Proceeding Overview
i. This proceeding will consider the rules and processes related to the Energy Resource Recovery Account (ERRA) and PCIA, the mechanisms by which unbundled customers are assessed the costs of generation resources procured by the IOUs on their behalf.

The Commission bifurcated the proceeding into two tracks - Track One is an expedited consideration of modifications to the market price benchmark (MPB) calculations and Track Two will be a more holistic review of potential changes to the ERRA and PCIA, potentially including, for example, sunsetting or re-vintaging [Publish Date] Agenda Date: 10/15/2026

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)
iii. Track 3
• 3a: Revisions to vintaging of generators and the MPB for RPS, Energy Only, and GHG-Free resources
• 3b: Structural changes to the PCIA to make it more accurate d. Status Update
i. December 1, 2025 - the California Community Choice Association (CalCCA) filed a Writ of Review (Writ) appealing a decision by the California Public Utilities Commission (CPUC) that will result in a shift of hundreds of millions of dollars from unbundled to bundled customers via the Power Charge Indifference Adjustment (PCIA). In its Writ, CalCCA explains that the CPUC’s arbitrary decision to change the PCIA methodology and apply that change to 2025 rates violates the longstanding prohibition against retroactive ratemaking, which is intended to ensure customer certainty and rate stability. 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;
[Publish Date] Agenda Date: 10/15/2026

• 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. The Energy Division proposes valuing the RECs (as opposed to the IOUs’ proposal to value the Pre-2019 Banked RECs at zero). CalCCA is evaluating ED’s four proposed valuation methods for Pre-2019 Banked RECs: (1) Load-share weighted RPS MPB; (2) DOE statewide renewable energy contract value assigned in D.11-12-018; (3) Valuation of Pre-2019 Banked RECs at 50 percent of current RPS MPB; and (4) “adjusted weighted mechanism” to value the RECs commensurate to the departed load share. Comments on the Staff Report are due with the Track 2 Opening Briefs, due May 22, 2026.
iv. May 12, 2026 - CalCCA filed testimony on Energy Division’s (Staff) report evaluating the pre-2019 banked RECs issue, rejecting Staff’s proposals and continuing to advocate for the RECs to be valued at the RPS MPB. CalCCA reiterated this stance in its subsequent rebuttal testimony filed May 22, 2026. In the rebuttal testimony, CalCCA put forth an alternative proposal to use a compliance-tier-weighted formula of 90% of the current year RPS MPB plus 10% of the PCC-3 market price. v. June 16, 2026 – In Track 2 of the PCIA proceeding, CalCCA filed its opening brief, asking the CPUC to value pre-2019 banked RECs at their compliance value through either 1) PCC-1 prices, 2) allocating the attributes, or 3) as an alternative to ED staff proposals, value the RECs at 90% RPS MPB and 10% PCC-3 price. CalCCA reiterated this stance in its reply brief, filed June 25, 2026.
vi. June 25, 2026 – CalCCA’s Petition for Writ of Review of the CPUC’s Track 1 PCIA decision applying the RA MPB changes retroactively to the 2025 true-up was summarily denied by the 3rd District Court of Appeals, with no substantive reasoning provided. Following this, CalCCA filed a Petition with the California Supreme Court on July 7, 2026, asking the higher court to uphold California’s prohibition on retroactive ratemaking.
vii. July 9, 2026 – CalCCA filed comments in response to an ALJ ruling seeking comments on Track 3 scope. CalCCA reiterated the stances it made throughout the CPUC workshops hosted on June 8, 9, and 15 regarding Track 3 scope. The [Publish Date] Agenda Date: 10/15/2026

workshops covered the topics of 1) structural changes to the PCIA, 2) refinements to the PCIA and ERRA methodologies, and 3) data access issues. CalCCA’s comments stated that Track 3 should be scoped broadly enough to enable consideration of a fair, long-term solution that will ensure indifference and rate stability for all ratepayers. The comments also recommended that the CPUC prioritize re-vintaging resources to ensure they do not stay in the PCIA portfolio indefinitely, modify the RPS MPB to better align with the newly adopted RA MPB methodology, and build in adequate time to evaluate data access proposals.
viii. August 13, 2026 – The CPUC issued a proposed decision on Track 2 that values pre-2019 banked RECs at $0 for CCA customers. This came as a surprise, as Energy Division and the Public Advocates Office had proposed valuing these RECs. ix. August 31, 2026 – CalCCA gave oral arguments on the Track 2 proposed decision and requested that the Commission issue an alternate proposed decision that values the RECs at one of the proposed valuation methodologies from either CalCCA, Energy Division, or the Public Advocates Office.
x. August 18, 2026 – The CPUC issued a scoping memo for the remaining tracks in the proceeding. Track 3 was split into 2 tracks, 3a and 3b. 3a will focus on revisions to the MPB for RPS, Energy-Only, and GHG-free resources, while 3b will look at making structural changes to the PCIA itself. There will also be a Track 4 to address any other outstanding issues.
xi. September 2026 – The CA Supreme Court agreed to take up CalCCA’s appeal of the Track 1 decision that dramatically changed the PCIA in 2026. We are waiting on the CA Supreme Court to issue guidance to the Appellate Court on how to proceed. This could potentially result in reduced PCIA fees and reimbursement for 2026 PCIA. xii. September 17, 2026 – The CPUC adopted a decision that assigns $0 value within the PCIA to RECs paid for by bundled customers before 2019 and now used by IOUs to offset their renewable requirements. The result is roughly $1 billion in RECs that current CCA customers paid for when they were still IOU customers that benefit only current IOU customers. CalCCA is filing an Application for Rehearing on October 22, 2026.
e. Background Documents/ Key Decisions
i. OIR to Update and Reform ERRA and PCIA Policies and Processes (Feb. 26, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=557860748 ii. Track 1 Scoping Ruling (Apr. 8, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=562084645 iii. D.25-06-049 adopted Track 1 RA MPB methodology changes (June 26, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=571242473 iv. Track 2 Scoping Ruling (Feb. 3, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M597/K166/597166403.PDF v. Track 2 Decision (Sept. 17, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M620/K372/620372336.PD vi. Track 3 and 4 Scoping Memo (Aug. 18, 2026)
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M615/K003/615003279.PDF f. Key Dates
[Publish Date] Agenda Date: 10/15/2026

i. Track one is completed at the regulatory level but could be revisited depending on the outcome of the appeal brought by CalCCA.
ii. Track 2:
• May 12, 2026 – Testimony on Staff Report
• May 22, 2026 – Rebuttal Testimony on Staff Report
• May 26, 2026 – Deadline to Present Settlement on Track 2 Issues or a Motion to Request Hearings
• May 27, 2026 – ALJ Ruling on the Need for Hearing
• June 2, 2026 – Evidentiary Hearing, if needed
• June 16, 2026 – Track 2 Opening Briefs
• June 25, 2026 – Track 2 Reply Briefs
• By August 17, 2026 – Proposed Decision issues
• September 17, 2026 – CPUC Decision
• October 22, 2026 – CalCCA Application of Rehearing Track 2 Decision iii. Track 3:
• 3a:
a. October 2026 – Joint Case Management Statement from IOUs and CalCCA
b. October 2026 – Staff report or proposal
c. December 2026 – Parties file proposals
d. Q1 2027 – Workshop on proposals
e. Q1 2027 – Party comments/reply comments on proposals f. Q1/Q2 2027 – Proposed Decision
• 3b:
a. A schedule will be issued in Q4 2026
iv. Track 4:
• TBD
g. Pioneer Lead: Jon Hart
• Safety & Reliability OIR– R.24-05-023:
a. Proceeding Overview
i. This multi-track rulemaking considers changes to policies related to the safety, reliability, and resiliency of electric distribution systems. The near-term focus of this proceeding is to develop processes for how 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:
[Publish Date] Agenda Date: 10/15/2026

• Transparency on the cause of outages to customers.
• Alternative approaches to reduce EPSS and PSPS events. • Protecting customers from increased costs while increasing reliability. c. Key Issues
i. The rulemaking focuses on evaluating the safety, reliability, and resiliency of the electric distribution system. A major component of the rulemaking is 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 equipment damage, EPSS, and first-responder requests. 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 outage 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 submitting annual safety and reliability metrics using a narrative reporting format. The submission identifies new metrics to report, but the draft likely requires additional clarification on terms and metrics. Pioneer's joint party to file reply comments requesting further clarification. ii. January 26, 2025 - Pioneer's joint party has filed reply comments requesting further clarification on the IOU’s proposed metrics. The party has advocated for the IOUs to provide meaningful analysis within future reports on how customers are being impacted by outages, including PSPS and EPSS events.
iii. July 10, 2026 – The Commission issued a proposed decision to adopt the IOUs’ Customer Reliability Report Template with modifications. Pioneer’s joint party successfully advocated for separate reporting and evaluation of PSPS and EPSS events. Adoption of this proposed decision would close the proceeding. iv. July 30, 2026 - Pioneer's joint party submitted comments on the proposed decision.

The comments address the need to keep the proceeding open to address meaningful reforms to safety and reliability.
v. August 13, 2026 - The Commission adopted the proposed decision requiring the IOUs to submit an Annual Electric Reliability Report based on the Template & Customer Reliability Schema developed through this proceeding, due on August 15th of each year. The IOUs will be required to hold a stakeholder workshop within 90 days after the first outage reports are submitted in 2027. The outage reporting [Publish Date] Agenda Date: 10/15/2026

requirement and Annual Electric Reliability Report will have a sunset date of August 2036. This proceeding is now closed.
f. Key Dates
i. Proposed Decision – July 10, 2026
ii. Final Decision – August 13, 2026
g. Pioneer Lead: Braden Henderson
• Disconnections – R.18-07-005:
a. Proceeding Overview
i. Rulemaking 18-07-005 was opened in response to Senate Bill (SB) 598 to address disconnection rates for both California’s electric and gas investor-owned utilities. SB 598 requires the commission to prohibit disconnecting service for nonpayment for a residential customer dependent on life-support equipment who is willing to enter into an amortization agreement and meets certain other conditions. The ruling was structured to occur in two phases; the first phase for immediate solutions to reduce disconnections, while the second phase is to evaluate the first phase results and establish long-term solutions.
ii. This proceeding requires the IOUs to administer two pilot programs: the Arrearage Management Plan (AMP) and the 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 assist low-income customers or customers facing hardship. c. Key Issues
i. Disconnections in this proceeding focus on situations where a utility intentionally disconnects a customer, mainly for residential nonpayment. Disconnections due to nonpayment concern regulators, service providers, and other customers because they shift the cost burden onto the rest of ratepayers. Programs and pilot programs help reduce disconnections by offering assistance to customers facing 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 support continuing AMP and PIPP, while IOUs submitted opening comments opposing 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 more [Publish Date] Agenda Date: 10/15/2026

disconnections, sunsetting the PIPP program, and refining the AMP program. Most parties favor extending the AMP program and do not support continuing 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 continuing the AMP program, a successor proceeding is expected to provide a venue to evaluate the ongoing implementation of AMP and other customer protections. iv. June 5, 2026 – Two Public Participation Hearings (PPH) on disconnections will be hosted by the Joint IOUs. Both PPHs are scheduled for August 6, 2026; the first will begin at 2pm and the second at 6 pm. Additionally, comments on TURN's proposal to lower the temperature threshold for suspending service disconnections from 100 degrees Fahrenheit to 90 degrees Fahrenheit are due June 10, 2026. v. June 22, 2026 – A Draft Resolution was issued refining the previous regulation which prevented IOUs from disconnecting customers when the 72-hour temperature look-ahead is predicted to be above 100 degrees or below 32 degrees Fahrenheit. The new resolution revises the upper threshold based on a heat index, specifically CalHeatScore (CHS) Level 2. CHS Level 2 roughly equates to 94 to 98 degrees Fahrenheit depending on the region’s humidity.
vi. August 13, 2026 – The Commission formally adopted the proposed decision to extend the AMP program’s sunset date to February 1, 2027. The Commission selected this date to align AMP with PIPP’s sunset date and avoid a lapse in the program if the Commission decides to extend the pilot program further or make it permanent.
f. Key Dates
i. Opening Comments – June 10, 2026
ii. Public Participation Hearing – August 6, 2026
iii. AMP Pilot Program Sunset Date – February 1, 2027
iv. Statutory Deadline – December 31, 2026
g. Pioneer Lead: Braden Henderson
• High-DER Future – R.21-06-017:
a. Proceeding Overview
i. The High Distributed Energy Resource (DER) proceeding is the rulemaking in alignment with the CPUC’s Distributed Energy Resources Action Plan 2.0, which aims to leverage DER planning to help achieve California’s renewable energy targets in the 2022-2026 timeframe. The proceeding is currently conducting Track Two and Track Three.
b. Potential Impact on Pioneer
i. This proceeding’s issues include energization of new customers and distributed resources. Other CCAs (i.e., Redwood Coast Energy Authority) have faced challenges interconnecting loads in their service territory; however, this type of interconnection and energization may not be a priority concern for Pioneer at the moment.
[Publish Date] Agenda Date: 10/15/2026

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 near-term grid modernization investments, implementing smart inverters to use advanced grid-service capabilities, and better aligning planned infrastructure investments with utility distribution planning.

Overall, this effort seeks to plan for high DER penetration and electrification to drive down costs over time.
ii. The Commission has resurfaced Track Two of this proceeding. Track Two, focused on DER Orchestration, was discussed earlier in the proceeding without any resulting decisions or consensus. The Commission is exploring how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value-added services.
d. Background Documents/ Key Decisions
i. R. 14-08-013 – OIR Regarding Policies, Procedures and Rules for Development of Distribution Resources Plans, Scoping Ruling (Jan. 26, 2016):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M157/K902/157902794.PDF e. Status Update
i. February 6, 2026 – Following the completion of the IOU’s electrification studies, the assigned commissioner has issued a ruling defining the schedule for Track Three to include an All-Party Workshop, Workshop Report, and Party Comment. ii. March 23, 2026 – The assigned commissioner issued a ruling requesting comments on how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value-added services. Opening comments are expected to question if IOUs are the appropriate parties to operate DER markets, and if there were to be operators, what guardrails are required. iii. April 20, 2026 – Parties filed opening comments in response to the Track 1 and Track 2 issues regarding orchestration of DERs. Most parties support the objective to implement DER orchestration. However, non-IOU parties are concerned that the Commission should first establish policies and processes before determining implementation pathways. The Commission also released the schedule for the 2026- 2027 Distribution Planning and Execution process.
iv. July 7, 2026 – The Assigned Commissioner’s Proposal on Flexible Service Connections was released. Primarily, the proposal seeks to require the IOUs to implement a standard offering where each IOU must evaluate whether a flexible connection mitigation approach can safely satisfy the customer’s requested capacity before a ratepayer-funded distribution upgrade associated with a customer is considered. This strategy aims to establish long-term flexible service connections enabled by DER orchestration and DER services. v. July 9, 2026 – The ALJ released two Track 2 Workshop Reports on “Distribution System Operator DER Orchestration” and “TSO [Transmission System Operator] - DSO Coordination.” The ALJ has requested comments and reply comments on a set of questions related to how to best establish an IOU-led DSO DER orchestration program.
[Publish Date] Agenda Date: 10/15/2026

vi. September 25, 2026 – The Commission released a proposed decision for Adopting an Application Process for Utility DER Orchestration. The IOUs would be directed to hire a consultant to lead a series of working group meetings outside of the proceeding to vet proposals for a common DER orchestration framework, then file a Joint IOU Application within 12 months of this resulting decision. The PD does not address the motion by the Center for Biological Diversity and the Utility Consumers’ Action Network, on September 9, 2026, to have the commission determine whether the conflict of interest inherent in the IOUs’ current cost recovery and investment structures impairs the effectiveness of DER orchestration. f. Key Dates
i. Issuance of Assigned Commissioner Proposal on Track 3 Issues – July 7, 2026 ii. Issuance of ALJ’s Questions on Track 2 Workshop Reports – July 9, 2026 iii. Track Three Opening Comments – July 21, 2026
iv. Track Two Opening Comments – July 27, 2026
v. Track Three Reply Comments – July 28, 2026
vi. Track Two Reply Comments – July 31, 2026
vii. Proposed Decision on Track 3 – Quarter 3 of 2026
g. Pioneer Lead: Braden Henderson
• Distributed Energy Resources – R.22-11-013:
a. Proceeding Overview
i. The Commission issued OIR 22-11-013 to achieve consistency of cost-effectiveness assessments, improve data access and use, and consider equipment performance standards for DER customer programs.
ii. The proceeding is broken up into the following phases and tracks:
• Phase 1: Focuses on issues related to the cost-effectiveness of customer DER programs, including updating the Avoided Cost Calculator (ACC) and policies to improve data usage and access to help customers make informed decisions about adoption, evaluation, and utilization of DERs.
a. Track 1: Examines how to make cost-effectiveness assessments more accurate and consistent across DER programs
b. Track 2: Examines the rules and requirements to improve data access to facilitate adoption, evaluation, and utilization of DERs by customers and other entities and to improve DER integration with the grid. c. Track 3: To examine additional guiding principles for the ACC and DER cost-effectiveness.
• Phase 2: Focuses on developing equipment performance standards. b. Potential Impact on Pioneer
i. The CPUC uses the ACC to determine DER’s primary benefits across Commission proceedings. Pioneer may want to follow this proceeding, as the ACC calculates costs related to generation capacity, energy, and RPSs that may affect electricity rates, portfolio planning, or DER program administration.
c. Key Issues
[Publish Date] Agenda Date: 10/15/2026

i. Currently in Phase I, the proceeding covers DER program cost-effectiveness issues, data access and use, and equipment performance standards. All of the latest updates and decisions related to the ACC fall under this proceeding. d. Background Documents/ Key Decisions
i. R.14-10-003 OIR to Create a Consistent Regulatory Framework for the Guidance, Planning and Evaluation of Integrated Distributed Energy Resources, Scoping Ruling (Jan. 5, 2015):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M143/K990/143990275.PDF e. Status Update
i. March 4, 2026 – The assigned commissioner issued a ruling setting the scope and schedule for Phase Three. Phase Three will be exploring the development and application of the ACC's Guiding Principles.
ii. April 29, 2026 - CPUC staff prepared a proposal on their proposed updates to the 2026 Avoided Cost Calculator. Staff also presented the proposal at a public workshop. At a high level, the proposed updates apply a single value to greenhouse gas (GHG) emission reductions, capped at the societal cost of carbon. iii. September 8, 2026 – The Commission adopted the Proposed Decision for incorporating updates to the Avoided Cost Calculator with some modifications from the staff proposal. Largely, this updates the calculation methodology rather than adopting any new applications for the calculator; the calculator uses a single electricity-based value for both electricity and natural gas GHGs and adjusts various factors within the model.
f. Key Dates
i. Opening Comments on the Proposed Decision – August 20, 2026 ii. Reply Comments on the Proposed Decision – August 25, 2026 iii. Decision on Phase 1 Track 3 Issues – September 3, 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 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 affect Pioneer’s ability to procure resources and implement programs. Delays in Rule 21 interconnections can have serious impacts to developer’s ability to cost effectively [Publish Date] Agenda Date: 10/15/2026

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 Screen Q, interconnection study costs, and interconnection application timelines. 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 favor a faster, 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 is ensuring that bioenergy resources are included in any reforms to the Rule 21 interconnection process, including reforms to address current delays in interconnecting resources. A scoping memo outlining the scope of issues and the proceeding schedule is expected in the coming weeks. ii. March 3, 2026 – The assigned commissioner released a scoping memo for Phase One. Phase One is prioritizing issues related to Screens Q & R, interconnection timelines, and the process for resources not interconnecting through the Net Billing Tariff (NBT) or Net Energy Metering (NEM) Tariff. These issues are significantly related to, but not limited to, the issues seen by biomass energy developers and the BioMAT program. Pioneer has been accepted as a party to the proceeding and will submit comments supporting changes to improve IOU compliance with interconnection timeline requirements.
iii. April 30, 2026 - Parties submitted opening comments regarding updates to Rule 21.

Comments responded to a set of questions defined by the Commission. Notably, the Commission requested input on compliance mechanisms it should consider for IOUs that may improve adherence to interconnection timelines. Pioneer submitted comments recommending the Commission adopt policies that protect interconnection customers from financial and programmatic burdens inflicted by IOU caused interconnection delays. While the IOUs explicitly opposed punitive measures for interconnection timeline noncompliance, many non-IOU parties offered proposals and concepts related to interconnection timeline compliance mechanisms for the Commission to consider. Most parties supported reevaluating the screening criteria for Rule 21, largely around Screen Q.
iv. May 29, 2026 – Parties submitted reply comments regarding the potential for Rule 21 updates. Reply comments were generally reflective of each party’s opening comments.
v. July 14, 2026 – The Commission issued a ruling directing the IOUs to submit Rule 21 interconnection application data to aid the Commission in its evaluation of party [Publish Date] Agenda Date: 10/15/2026

comments. The data request largely seeks information on application fees and the time and costs associated with the IOUs handling Rule 21 interconnection requests. f. Key Dates
i. Opening Comments to Phase One Scoping Memo – April 30, 2026 ii. Reply Comments to Phase One Scoping Memo – May 29, 2026 iii. IOU Responses to Ruling – August 11, 2026
iv. Party Reply Comments – August 28, 2026
g. Pioneer Lead: Braden Henderson
1 Attachment 3: Communications, Outreach & Customer Care Updates Date: 10/15/2026
NOTABLE ACHIEVEMENTS – SEPTEMBER 2026
• Successful email campaign results in a 99.2 % delivery rate and 31% open rate, exceeding industry standards
• Social media following and presence continue to grow, with notable engagement from California Senator Megan Dahle
• Earned media coverage and social media conversation have continued positive sentiment and reinforced Pioneer key messages about choice and community partnership WEBSITE: PROGRAM INTEREST REMAINS STRONG
Website traffic decreased by more than 50% month to month (9,400 visitors in September compared to 22,652 in August), reflecting scaled-back paid advertising. Program pages remained popular, with the newly updated “Residential Programs” page getting a bump in traffic.

An e-blast sent to customers promoting programs generated significant traffic to all program pages, with 1,387 page visitors per day on the days following its release (compared to the September monthly average of 313 users per day).

Top 5 pages visited:

1. PowerShift Rewards

2. AC Tune-Up

3. Home

4. GridGen

5. Residential Programs

CUSTOMER CARE
Call Center
• 523 calls (down 28% from August)
• Billing inquiries and programs were primary topics
• (Customer survey data was not available at the time this report was prepared.) Chatbot:
• 458 transactions
• 155 live conversations (down 11% from August)
• Average conversation duration was 16 minutes, 45 seconds (down 21% from August) • Average customer satisfaction rating is 4.3/5

DIRECT MAIL GIVES PROGRAMS A LATE SEASON BOOST
Pioneer sent a final e-blast to customers promoting the end of the season for AC Tune-Up and PowerShift Rewards programs. The email was sent to more than $106,000 customers with a

99.2% delivery rate and 31% open rate – far exceeding industry standards. The email resulted in 240 additional PowerShift Reward program enrollments in the 24 hours after the email was sent.

OUTREACH: PIONEER IN THE COMMUNITY
September’s community outreach efforts focused on building relationships with expansion communities through meetings, sponsorships, and presentations highlighting the benefits of

Pioneer. Additionally, staff supported expansion communities with webpage guidance and outreach support to strengthen communications and visibility. These activities, along with community outreach initiatives throughout the month, helped increase engagement, foster partnerships, and support continued community relations.
• Diablo Canyon Power Plant - Board member tour
• City of Chico Council meeting – expansion update
• City of Chico – assist with webpage development
• City of Chico – briefing for new City Manager
• City of Chico- meeting with Assistant City Manager
• Colusa County Board of Supervisors – expansion update • Colusa County – comms planning with PIO
• Colusa County- Work with Assistant CAO on webpage
• Colusa County Chamber of Commerce meeting – demographic overview, community issues and concerns
• North Zone Publications (serving Yuba, Sutter, Butte and Colusa Counties) on background • Oroville NAACP – expansion presentation
• Town of Loomis – meeting to discuss FruitShed Festival planning • Tuolumne County CAO – questions regarding webpage
• City of Yuba City – meeting with City Manager
• Gold Country Fair sponsorship
• City of Yuba City – expansion update presentation
• City of Williams - expansion update presentation
• City of Willows- web page support
• South Placer County Rotary – programs presentation
• Rocklin Chamber – programs update
• Prepare Expansion Communities Resource Guide
• City of Williams – webpage support
• El Dorado County Chamber – monthly lunch featuring Assemblymember Heather Hadwick • Community Outreach Specialist Interviews
• Butte County - expansion update presentation
• Angels Camp – respond to expansion interest inquiry and provide a Pioneer presentation • Town of Paradise Chamber CEO lunch
• Oroville Chamber of Commerce; Discussion about biomass and possible sponsorship opportunities
• Placer/El Dorado/Nevada Counties - Feeding the Foothills “Forks and Forklifts” event sponsorship and attendance
• Loomis Acres of Hope event sponsorship and attendance • Roseville Joint Government Relations Committee meeting • River Valley Community Bank Anniversary lunch

SOCIAL MEDIA
September brought new followers and increased engagement across all platforms, with member agencies and community partners reacting favorably to sponsorships. Considerable engagement came from expansion communities, with online conversation demonstrating that people are well-informed and looking forward to having a choice – a sign that repetition and continuity of message are working.

Notable engagement came from Senator Megan Dahle, who now follows Pioneer:

Top performing posts for September 2026:

Facebook Instagram
AB 706 Acknowledgements
15% engagement (avg. 10%)
Liked by Sen. Megan Dahle
Localized Lighting Savings Tip
33% engagement (avg. 20%)

EARNED MEDIA
Pioneer’s earned media profile continues to grow, largely due to expansion. Fourteen different articles mentioned Pioneer, reaching an audience of more than 185,000 and a media value of nearly $6,000. Local reporters continue to reach out to Pioneer for background information and comment, particularly related to expansion.

Outlet Medium Topic Content Audience
Reach
KPAY - AM Radio Expansion City of Chico moving closer to starting service with Pioneer
Community Energy
23,800
KPAY.com Online Expansion Pioneer Community Energy
comes to Butte County
1,500

ChicoSol.com Online Expansion /
Community
Reinvestment
Solar Farm tentatively planned
for Skyway
3,900
Chico
Enterprise
Record
Online /
Print
Expansion Butte County Residents
presented with alternative
energy option
5,000
Oroville
Mercury
Register
Online /
Print
Expansion Butte County Residents
presented with alternative
energy option
396
Chico
Enterprise
Record
Online Expansion Another energy option coming
to North State
10,000
Oroville
Mercury
Register
Print Expansion Another energy option coming
to North State
5,900
Action News
Now
Online /
Print
Community
Reinvestment
300-megawatt solar farm will
soon be proposed in Butte
County
10,500
The
Northstate's
News
TV Expansion 1,000
Chico
Enterprise
Record
Online /
Print
Expansion Hits and Misses op-ed, positive
story about Pioneer expansion
10,000
The
Northstate's
News
TV Expansion 772
Chico
Enterprise
Record
Online /
Print
Community
Reinvestment
Pioneer mentioned as a
potential buyer of a Butte Co.
solar farm in development
10,000
ChicoSol.com Online Community
Reinvestment
Pioneer mentioned as a
potential buyer of a Butte Co.
solar farm in development
3,900
Territorial
Dispatch
Online Expansion Pioneer will begin providing
power to Yuba City in October
2027
270
Blackrock Online Google
Prepaid Bond
Pioneer's prepaid-energy
transaction with Alphabet
98,300
185,238

Attachment: 4 Program Updates
Date: 10/15/2026

PROGRAMS SUMMARY
Pioneer Program Webpage
• Redesigned the Programs Webpages to promote featured programs for our customers and increase access to savings opportunities
• Enhancing partnership and coordination efforts with NREN (Northern Rural Energy Network) to promote rebates & incentives to our customers
CORE Pilot (Continuous Optimization of Resources and Energy) • Proposals received from Implementation firms with interviews scheduled through Mid-October. • Energy efficiency program targeted for large C&I, Ag, Municipal organizations • Implementation partner will act as liaison between customer and energy rebates, educational materials, and energy efficiency environments
Incentive Finder
• 2,977 searches since January 2026
• Data shows that customer interest in HVAC, home appliance, battery, and insulation rebates is strong • New contract with PaulosAnalyis for 2 years of the Residential Incentive Finder tool, with the addition of the development of a Commercial Incentive Finder tool.

AC Tune-Up
• 2,192 applications received since launching on April 1st, 15% more than the number received during the same period in 2025. The full 2026 season’s comparison to 2025 will be available in the November Programs Report.
• Pioneer’s new customer portal, designed to make it easier for customers to track their application status and for staff to track program data, is running effectively. • Season ended on October 1, with final applications received through October 15 PowerShift Rewards
• 2026 season ends on October 31
• 3,331 customers are currently enrolled
• Improved compliance protocol with CAISO’s Demand Response Registration System to ensure credible load shifting resources.
• This Summer has had milder temperatures, resulting in 6 events this season.

GridGen
• 62 projects completed and received final inspection
• 58 projects completed and received Permission to Operate • 84 customers in the active pipeline
• 571.89 KW of solar capacity installed
• 550,870.17 kWh of clean energy generated since program launched Hourly Flex Pricing Pilot
• Annual true-up period began in August, after 12 consecutive months of service • Validation is in process, with bill credits expected in November • Two customers enrolled in the program (19 meters/accounts) LED Discount Lighting
• Requested to the Board for a contract extension to continue offering this program through FY26-27 • 32 local retailers are currently participating
• About 100,000 units of inventory sold since program launch • Program remains very popular with customers and retail partners

OVERALL PERFOMANCE TOTAL
Objectives by Status 19 3 0 0 22 CHECK
Tasks by Status 45 2 0 3 50 CHECK

EXECUTVIE SUMMARY
Status

BE A COMMUNITY PARTNER

1.1 Community Engagement On Target

1.2 Community Advisory Committee Representation Off Target

1.3 Launch & Monitor Energy Efficiency Programs On Target

1.4 Legislative & Regulatory Representation On Target

1.5 Build Local & Regional Partnerships On Target

BE FISCALLY STRONG & RESILIENT

2.1 Maintain Investment Grade Credit Rating On Target

2.2 Financial Integrity & Transparency On Target

2.3 Expansion of Pioneer's Service Territory On Target

2.4 Community Reinvestment On Target

2.5 Balanced Approach to Rate-Setting On Target

PROVIDE AN EXCEPTIONAL CUSTOMER EXPERIENCE

3.1 Stable & Competitive Rates On Target

3.2 Responsiveness to Customers Needs On Target

3.3 Utilize Technology to Improve he Customer Experience On Target

3.4 Increase Customer Understanding On Target

ACHIEVE OPERATIONAL OPTIMIZATION

4.1 Compliance On Target

4.2 Opportunities On Target

4.3 Protection of Customer Data On Target

4.4 Risk Management Best Practices Off Target

BE A GREAT PLACE TO WORK

5.1 Employer of Choice On Target

5.2 Align the Culture with the Employees Off Target

5.3 Employee Engagement On Target

5.4 High Performing Workforce On Target
22 KEY
Within 15% of target = "On Target"
Within 30% of target = "Off Target"
Grey = Not Started
Greater than 30% of target - "Critical"
Finance & Administration

PIONEER COMMUNITY ENERGY STRATEGIC PERFORMANCE SUMMARY
Goal Owner
Communications
Programs
Programs
Leg & Reg
Status Through Quarter 1 of Fiscal Year 2026-27
Communications
Finance
Finance
Administration
Power Supply
All Departments
I.T. & Communications
Finance & Administration
Communications
Communications
Power Supply & Leg/Reg
Power Supply
Info. Technology
Finance & Administration
Human Resources
Human Resources
Human Resources

PERFORMANCE SUMMARY DETAIL
Status

BE A COMMUNITY PARTNER

1.1 Community Engagement

1.1.1 Achieve 85% participation rate for communities in Placer & El Dorado Counties On Target

1.1.2 Achieve 95% participation rate for communities joining after 2022 On Target

1.2 Community Advisory Committee Representation

1.2.1 75% of communities represented on advisory committee Off Target

1.2.2 Advisory Committee considers three new programs to the Board annually On Target

1.3 Launch & Monitor Energy Efficiency Programs

1.3.1 Develop, launch, and monitor energy efficiency programs On Target

1.4 Legislative & Regulatory Representation

1.4.1 Bills presented and passed through the legislature that support issues important to our Members On Target

1.4.2 Represent our customers On Target

1.4.3 Focus on issues important to our region On Target

1.5 Build Local & Regional Partnerships

1.5.1 100% participation in Member's Chamber of Commerce On Target

1.5.2 Strategic partnerships with regional organizations On Target

1.5.3 Be an economic engine in our communities On Target

BE FISCALLY STRONG & RESILIENT

2.1 Maintain Investment Grade Credit Rating

2.1.1 Adopt budgets that maintains A- credit rating On Target

2.2 Financial Integrity & Transparency

2.2.1 Annual financial audit is free of material weakness and significant deficiencies On Target

2.2.2 Review financial policies annually Off Target

2.3 Expansion of Pioneer's Service Territory

2.3.1 Evaluate potential new members that are like-minded On Target

2.3.2 Ensure expansion is financially feasible through impact assessment studies On Target

2.4 Community Reinvestment

2.4.1 Sponsorships that are strategic On Target

2.4.2 Regional non-energy procurement of goods and services On Target

2.4.3 Execute three BioMAT opportunities On Target

2.4.4 Apply the Local Feed-In Tariff in power supply Not Started

2.4.5 Preference to local projects for power supply On Target

2.5 Balanced Approach to Rate-Setting

2.5.1 Rate setting that provides value to the ratepayer and long-term health of Pioneer On Target

PROVIDE AN EXCEPTIONAL CUSTOMER EXPERIENCE

3.1 Stable & Competitive Rates

3.1.1 Pioneer's rate are competitive to PG&E's generation rate On Target

3.1.2 Rate changes should be minimal On Target

3.2 Responsiveness to Customers Needs

3.2.1 80% of all calls answered within 45 seconds On Target

3.2.2 Customer receives same message from Pioneer staff and Calpine call center On Target

3.3 Utilize Technology to Improve he Customer Experience

3.3.1 Focus on website updates to most visited pages On Target

3.3.2 Chatbot capabiliies expand On Target

3.3.3 Conduct in-person field days in the community On Target

3.3.4 Collaborate with other CCAs to explore technological tools to improve the customer experience On Target

3.4 Increase Customer Understanding

3.4.1 Produce educational videos and webinars to improve customer education On Target

3.4.2 Extend programs into school scholarship competitions Not Started

ACHIEVE OPERATIONAL OPTIMIZATION

4.1 Compliance

4.1.1 No penalties or fines from various regulatory agencies On Target

4.2 Opportunities

4.2.1 Pursue revenue generating initiatives On Target

4.2.2 Achieve cost reduction initiatives On Target

4.2.3 Procure power supply that is least cost-best fit to maintain rate competitiveness On Target

4.3 Protection of Customer Data

4.3.1 Conduct annual IT audits and triennial AMI audit required by the CPUC On Target

4.3.2 Ongoing cybersecurity training for staff On Target

4.4 Risk Management Best Practices

4.4.1 Conduct quarterly risk oversight committee meetings On Target

4.4.2 Biennial review of Energy Risk Management Policy and Credit Guidelines On Target

4.4.3 Annual reviews of operational risk such as employee handbook and insurances On Target

4.4.4 Conduct weekly employee meetings for recommendations of business practices On Target

BE A GREAT PLACE TO WORK

5.1 Employer of Choice

5.1.1 Conduct triennial compensation study On Target

5.1.2 Annual health and welfare review with Governance Committee On Target

5.2 Align the Culture with the Employees

5.2.1 Annual survey of employees On Target

5.2.2 Staff training on internal and external customer service Not Started

5.3 Employee Engagement

5.3.1 Achieve at least 100 hours of volunteer activity annually On Target

5.3.2 Employee appreciation events for a job well done On Target

5.4 High Performing Workforce

5.4.1 Support training and development of staff On Target

5.4.2 Supervisor incorporate training opportunities as part of the annual performance reviews On Target 50 KEY
Within 15% of target = "On Target"
Within 30% of target = "Off Target"
Grey = Not Started
Greater than 30% of target - "Critical"
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Pioneer Community Energy
Glossary of Terms
CAISO - California Independent System Operator - a non-profit independent system operator that oversees the operation of the California bulk electric power system, transmission lines and electricity market generated and transmitted by its members (~80% of California's electric flow). Its stated mission is to "operate the grid reliably and efficiently, provide fair and open transmission access, promote environmental stewardship and facilitate
effective markets and promote infrastructure development. CAISO is regulated by FERC and governed by a five-member governing board appointed by the governor.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

See Demand.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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