Pioneer Community Energy Board of Directors
July 23, 2026

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
i. August 10, 2026 – LSEs' Individual IRP Plans Due
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. 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 [Publish Date] Agenda Date: 7/16/2026

ii. PD on 2025 RPS Procurement Plans (November 14, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M587/K328/587328286.PDF iii. Pioneer Community Energy Final 2025 RPS Procurement Plan (January 26, 2026):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M596/K418/596418446.PDF f. Key Dates
i. June 12, 2026 – Draft RPS Procurement Plan is due
g. Pioneer Lead: Chau Pham
• Resource Adequacy (RA) – R.23-10-011; R.25-10-003:
a. Proceeding Overview
i. This proceeding aims to ensure the reliability of CA's electricity supply by requiring that LSEs procure sufficient resources to meet their load plus a planning reserve margin (PRM). The RA program recently implemented a slice of day (SOD) framework, ensuring LSEs are compliant every hour of the worst day of the month. b. Potential Impact on Pioneer
i. Pioneer is required to comply with RA procurement requirements and filings. Annual (year ahead) filings are due on October 31 each year and monthly (month ahead) filings are due 45 calendar days prior to the compliance month. Furthermore, RA requirements have significant impacts on the procurement market which Pioneer operates in. Therefore, Pioneer advocates for RA procurement requirements and policies that minimize adverse effects on the RA market. c. Key Issues
i. Advocate for refinements in the RA program that minimize RA requirements (based on robust modeling) to ensure adequate market availability and guard against RA price volatility
ii. Advocate for simplifying RA showings/ compliance requirements to the greatest extent possible
d. Status Update
i. December 12, 2025 - A Scoping Ruling was issued with the following items in scope for the Track 1 of the RA proceeding:
• Adoption of local and flexible requirements;
• Accreditation for long duration energy storage;
• Development of the Unforced Capacity Methodology framework; • Accreditation for wind and solar;
• SOD transactability issues;
• Residual Unit Commitment for RA resources
• Energy only resources; and
• Other time sensitive issues identified by the CPUC or parties in proposals ii. January 23, 2026 - CalCCA filed RA Track 1 proposals including 1) using data center interconnection info, instead of data center IEPR forecast, to inform RA requirements, 2) counting of energy only (EO) co-located resources under SOD, 3) ensuring local RA central procurement entity (CPE) data request is used consistently among CPEs to ensure there is no over-procurement, and support publicizing the CPE data request responses.
[Publish Date] Agenda Date: 7/16/2026

iii. March 3, 2026 – CalCCA filed an opening proposal on Transactability Issues, responding to ED’s Transactability Report and recommending adoption of hourly load obligation trading. CalCCA argued that the report does not accurately address the issues with the SOD framework or the affordability implications of hourly load obligation trading. CalCCA proposed the CPUC adopt hourly load obligation trading to allow LSEs to transact at the same level of granularity as the SOD requirements and invest in software and systems to automate the RA validation process to assist with administrative burden or adopt temporary guardrails to aid in assessing compliance. iv. March 6, 2026 – CalCCA filed opening comments on Track 1 proposals, clarifying their proposal to incorporate data center load into RA allocations based on specified development milestones, rather than forecasted load. CalCCA also sought procedural and timeline clarifications on PG&E’s proposal that voluntary changes to the effective date of an LSEs’ CPUC-approved implementation plan does not qualify as “load migration” in the annual RA allocation process. The comments also expressed views on various other party proposals, which Pioneer did not directly engage in. v. March 20, 2026 – CalCCA filed reply comments on Track 1 proposals, providing counterarguments to several parties who raised objections to the data center load allocation proposal and PG&E’s recommendation to reject the proposal to clarify use of the local RA CPE data request. CalCCA also raised objections to Cal Advocates’ long duration energy storage (LDES) counting proposal with similar concerns as multiple other parties that it likely underestimates LDES’ charging capability. vi. March 30, 2026 – CalCCA filed reply comments on Transactability Issues, responding to Vistra’s opposition to hourly load obligation trading (HLOT) and echoing environmental groups’ support of HLOT as a mechanism to promote affordability and reduce reliance on fossil fuels.
vii. June 1, 2026 – The Track 1 PD was issued, which adopts local capacity obligations for 2027-2029, flexible capacity obligations for 2027, and program refinements based on party proposals. The PD rejected CalCCA’s hourly load obligation trading and data center load proposals. The PD adopted CalCCA’s proposal for local RA CPE data request transparency and the proposal to allow co-located EO resources to count for offsite storage charging sufficiency, but not for general RA. The PD also adopted a proposal to maintain the status quo for requiring zero-dollar bidding for capacity products, and to specify that the resource owner is not eligible for capacity-related revenue payments, despite several parties’ objections that these rules are not compatible with the evolving nature of the CAISO’s Extended Day Ahead Market. viii. June 30, 2026 – The Track 1 PD was revised and approved at the July 2, 2026 CPUC voting meeting. The revised PD did not adopt the recommendations CalCCA proposed in its comments on the PD, primarily to remove the status quo requirements for zero-dollar bidding and revenue prohibition on capacity products. e. Background Documents/ Key Decisions
i. Issuance of OIR 25-10-003 (October 15, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Published/G000/M583/K934/583934825.PD F
ii. Scoping Ruling (December 12, 2025):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M590/K884/590884355.PDF iii. ALJ Ruling on ED’s Transactability Report (February 23, 2026):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=600063407 [Publish Date] Agenda Date: 7/16/2026

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 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 presents both challenges and opportunities to Pioneer. If Pioneer is going to provide generation service to these customers, it needs visibility into which ones are expected to come online in its service territory (if any) for procurement planning purposes. It will also need to have a commitment from these customers far in enough in advance for Pioneer to procure resources in advance of any compliance deadlines to serve these new loads.
c. Key Issues
i. Ensure Pioneer obtains information regarding new large loads when that information is obtained by the IOU, either before or at the time of a customer request for interconnection with the IOU’s transmission or distribution system; ii. Ensure the ability of Pioneer to adequately prepare to serve customers through timely access to information regarding large loads; and iii. Support customer choice of generation providers through ensuring IOUs and CCAs compete on a level playing field.
d. Status Update
i. May 8, 2026 – PG&E requested CPUC approval of a partial settlement agreement between itself, CalCCA, CalAdvocates, and Sierra Club. The relevant terms of the settlement agreement are as follows:
• Information Sharing (Under New NDA)
a. Interconnection Inquiries:
i. PG&E shall the same information regarding all transmission-level retail interconnection inquiries that it includes in [Publish Date] Agenda Date: 7/16/2026

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 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. 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 [Publish Date] Agenda Date: 7/16/2026

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
f. Key Dates
i. March 13, 2026 – Limited Opening Testimony on additional cost allocation questions in a January 9, 2026 Ruling
ii. April 8, 2026 – Rebuttal Testimony on additional cost allocation questions iii. April 15, 2026 through April 17, 2026– Evidentiary Hearings iv. questions
v. May 8, 2026 – Opening Briefs on additional cost allocation questions vi. May 22, 2026 - Reply Briefs on all issues
vii. Late July 2026 – Proposed Decision
viii. August/September 2026 – CPUC Decision
g. Pioneer Lead: Braden Henderson
• Demand Response – R.25-09-004:
a. Proceeding Overview
i. This rulemaking will revisit and enhance the CPUC's "demand response guiding principles, policies, and data system and process requirements." In particular, the rulemaking seeks to enhance the consistency, predictability, reliability, and cost-effectiveness of demand response (DR) resources. Issues that the CPCU could address in this proceeding is dual participation of DR resources among different programs, adjustments to the DR guiding principles, and integration into other systems and process, including resource adequacy slice of day (RA SOD) and the CAISO market.
b. Potential Impact on Pioneer
i. Under the law, demand response and energy efficiency are the first resources that electric corporations use to meet their needs, so there is a statutory mandate to generally include it in the California resource mix. There could also be a specific impact on Pioneer's programs that fall under the umbrella of demand response, including the PowerShift Rewards program.
c. Key Issues
i. Pursue systems and processes that support timely and consistent Pioneer access to customer interval data, both billing-quality and non-billing-quality ii. Ensure Pioneer customers have equitable access to demand response resources [Publish Date] Agenda Date: 7/16/2026

iii. Ensure new policies or programs do not encroach on Pioneer rate and program autonomy
d. Status Update
i. July 7, 2026 - ALJ ruled to eliminate the testimony, evidentiary hearing, and briefs from the schedule as no disputed material facts or questions of law, regarding the Bridge Year Funding Issue, emerged from the comment and reply comment periods.
e. Background Documents/ Key Decisions
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. Q2 2026 - Staff Proposal on Data Systems and Processes iv. Q3 2026 – Proposed Decision on IOU DR Bridge Funding v. Q4 2026 – Proposed Decision on all other issues
g. Pioneer Lead: Braden Henderson
• PG&E Energy Resource Recovery Account (ERRA) Compliance and Forecast:
a. Proceedings Overview
i. Generally, the ERRA Compliance proceedings review IOU accounting for its generation costs in the previous year, which includes accounting related to the Power Charge Indifference Adjustment (PCIA) and Portfolio Allocation Balancing Account (PABA). The purpose is to ensure accuracy and compliance with legal requirements, including CPUC rules and decisions.
b. Potential Impact on Pioneer
i. Although typically not as contentious as the ERRA Forecast proceedings, PG&E's applications in the ERRA Compliance proceedings often include errors or non-compliant activities which, when corrected, result in a credit to unbundled customers via the PCIA which is incorporated in the ERRA Forecast proceedings. This proceeding is also an opportunity to review PG&E's activities related to its PCIA resources, although transparency is always a challenge.
ii. This is the proceeding in which the PCIA revenue requirement for the following rate year (i.e., 2026 in this proceeding) is established. Parties and the CPUC arrive at the revenue requirement by reducing the costs of the PCIA resources by their value and adding any over or under-collection of the PCIA from the current rate year (i.e., 2025 in this proceeding). That revenue requirement is then assigned to customer vintages depending on the vintage of the resource to develop PCIA rates. Given all of Pioneer's customers pay PCIA rates, Pioneer's goal is to ensure that its customers are only [Publish Date] Agenda Date: 7/16/2026

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
i. No updates.
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 [Publish Date] Agenda Date: 7/16/2026

d. Key Dates
i. To be determined in a forthcoming Scoping Ruling.
e. Pioneer Lead: Chau Pham
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 are going to decrease, but that rate is expected to increase from now until the October update and annual true-up due to PG&E using outdated values (2026 GRC revenue requirement, 2026 RA/ RPS MPBs).

The application projects a 1.7 c/kWh (7.3% decrease over present system average rates) for CCA/DA customers and an increase of 1.9 c/kWh (5.7% increase over present system) for bundled customers. NewGen found that the biggest driver in downward pressure on the PCIA and upward pressure on generation rates is the [Publish Date] Agenda Date: 7/16/2026

change in PG&E's balancing accounts from 2025 to 2026, which are overshadowing the low energy prices.
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. Protests due June 17, 2026
e. Pioneer Lead: Chau Pham
• PG&E General Rate Case (GRC) Phase 1 – A.25-05-009:
a. Proceeding Overview
i. In four-year cycles, IOUs submit GRC applications for authority to adjust rates and charges for electric and gas service based on a future test year (TY). The revenue requirements include electric and gas distribution system costs, administrative expenses, and customer service costs.
ii. In the GRC Phase 1, the CPUC establishes the IOU's overall revenue requirement, which is later allocated in rates to different customer classes in the GRC Phase 2.

This includes establishing the operating and capital costs to be recovered for the IOU's transmission, distribution, and generation functions. b. Potential Impact on Pioneer
i. The costs of PG&E's Power Charge Indifference Adjustment (PCIA) generation resources will be established here and later recovered through the PCIA rates via the ERRA Forecast proceeding.
ii. This proceeding will also establish revenue requirements for PG&E programs that could benefit customers in Pioneer's service territory, including resiliency and backup power initiatives to support areas disproportionately impacted by outages. c. Key Issues
i. Ensure accuracy and reasonableness of forecast costs ii. Ensure revenue requirements are properly allocated to PCIA vintages iii. Ensure costs are properly allocated across major work categories iv. Prevent unwarranted or unreasonable increases to CCA service fees d. Status Update
i. February 13, 2026 – CalCCA filed testimony on PG&E’s application proposing the various changes that would lower the generation revenue collected through the PCIA, including, but not limited to:
• Removing hydro facilities that erroneously remain on PG&E’s books and those that are no longer used and useful in providing generation services for the benefit of customers from the Electric Generation revenue requirement while recovering any remaining balance of the original investment through a regulatory asset, with no return on rate base and
• Moving eight hydro facilities into a more recent vintage for the purposes of PCIA cost recovery to reflect the fact that the substantial proposed investments in these assets of over $2 billion would result in a significant [Publish Date] Agenda Date: 7/16/2026

overhaul of these facilities, supporting life extensions as well as changed functions for these assets.
ii. April 27 – May 6, 2026 – CalCCA is participating in Evidentiary Hearings. CalCCA’s witness Ryan Matley is scheduled to be cross-examined on May 13, 2026. CalCCA’s cross-examination of PG&E’s witnesses will focus on hydro facility costs, proposed investments, and the correct vintaging of those hydro investments. PG&E has hydro assets that are on the books but have not been used, as well as new investments that may require re-vintaging.
e. Background Documents/ Key Decisions
i. PG&E Phase 1 2027 Application (May 15, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=566363587 ii. PG&E Phase 1 2027 Scoping Ruling (July 31, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=575112973 f. Key Dates
i. Intervenors’ testimony - February 13, 2026
ii. Rebuttal testimony - March 31, 2026
iii. Case Management Conference
iv. Statement and Motions for Settlement - April 13, 2026 v. Evidentiary hearings - Starting April 27, 2026
vi. Opening briefs - June 19, 2026
vii. Reply briefs - July 10, 2026
viii. Proposed decision - March 2027
ix. Commission decision May - 2027
g. Pioneer Lead: Chau Pham
• PG&E General Rate Case Phase 2 – A.24-09-014:
a. Proceeding Overview
i. In four-year cycles, IOUs submit GRC applications for authority to adjust rates and charges for electric and gas service based on a future test year (TY). The revenue requirements include electric and gas distribution system costs, administrative expenses, and customer service costs
ii. The GRC Phase 2 is focused on the design of PG&E's rates, and includes proposals for real-time pricing rates. This follows the GRC Phase 1, which determines the cost of service.
b. Potential Impact on Pioneer
i. PG&E is proposing to escalate fees for meter data management, rate ready consolidated billing fee, and bill-ready consolidated billing fee. ii. How PG&E implements RTP and how pricing and usage data is transferred to CCAs will impact CCAs' ability to implement their own dynamic pricing programs and potential implicate their compliance with the load management standards (LMS) of the California Energy Commission (CEC).
[Publish Date] Agenda Date: 7/16/2026

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

If CCAs want to use a different generation marginal RTP, they may contract with another entity to develop that price and calculate their unbundled customers’ generation bill.
c. Key Issues
i. Ensure that CCAs have access to data needed to implement dynamic rates for any CCA that chooses to do so and ensure that PG&E's implementation of dynamic rates does that impede CCA ability to comply with CEC LMS rules. d. Status Update
i. March 9, 2026 – CalCCA submitted testimony recommending that the CPUC:
• Reject PG&E’s proposed 20 percent increases to its CCA Service Fees; • Order PG&E to complete a cost study to support any future recommended changes to its CCA Service Fees;
• Order PG&E to: (1) cap its revenues associated with the CCA Service Fees at the cost levels included in its forecast for these services provided in its 2027 Phase I General Rate Case (GRC) Application (A.) 25-05-009; and (2) track any revenue received above that cap and refund this amount to unbundled customers via PG&E’s next Energy Resource Recovery Account (ERRA) compliance proceeding;
• Reject PG&E’s proposal to update its CCA Service Fees via Tier 2 Advice Letters in the future, and instead reiterate that PG&E may only update these fees via a GRC application, and that any such update must be supported by up-to-date information regarding PG&E’s actual costs incurred in the provision of these services; and
• Order PG&E to update its Provider of Last Resort (POLR) fee for CCA customers by: (1) submitting supplemental testimony in this proceeding regarding its actual costs as the POLR to process a customer’s voluntary return to bundled service in 2026, using up-to-date data on PG&E’s processing times and labor costs; and (2) shortly after PG&E’s final implementation of its Billing Modernization Initiative (BMI) project, submitting testimony in its next GRC application regarding its actual costs as the POLR to process a customer’s voluntary return to bundled service, using up-to-date data on PG&E’s processing times and labor costs
e. Background Documents/ Key Decisions
i. PG&E Phase 2 2023 Application (Sept. 30, 2024):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=541493803 ii. PG&E Phase 2 2023 Scoping Ruling (Mar. 21, 2025):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=560273042 f. Key Dates
i. Cal Advocates Testimony -January 9, 2026
ii. Intervenors' Testimony – March 9, 2026
[Publish Date] Agenda Date: 7/16/2026

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: Chau Pham
• Provider of Last Resort (POLR) – R.21-03-011:
a. Proceeding Overview
i. Track 1 of the POLR proceeding serves to determine/ update the methodology for the financial security requirement (FSR) that CCAs have to post, to ensure the IOUs (Current POLRs) have the capital to serve customers in case of an emergency mass return. Track 2 of the proceeding gauged interest from any LSEs/ IOUs who are interested in taking on the role of POLR.
b. Potential Impact on Pioneer
i. Pioneer would like to minimize changes to the FSR methodology that could increase it. It's also important to stay up to date with any changes in the process/ timing of posting Pioneer’s FSR.
c. Key Issues
i. Prevent the requirement for the POLR to procure or hedge in advance of customer return
ii. Ensure modifications to the FSR are balanced and improve accuracy iii. Adjust the FSR calculation to account for risk of customer return through an unsecured credit limit
iv. Reject the adoption of PG&E’s outsized “liquidity pool” that would remove the revenue offset component of the calculation entirely
v. Ensure non-IOU LSEs are able to serve as POLR under similar rules as the IOU as POLR
d. Status Update
i. No updates.
e. Background Documents/ Key Decisions
i. Scoping Ruling (Sept. 16, 2021):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M407/K765/407765425.PDF ii. CalCCA Comments (July 5, 2022) on Ruling Requesting Comments on the FSR and Re-Entry Fee (May 2, 2022):
https://docs.cpuc.ca.gov/SearchRes.aspx?DocFormat=ALL&DocID=490740399 iii. ED Staff Proposal (Jan. 6, 2023):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M500/K762/500762116.PDF iv. D.24-04-009 (Apr. 18, 2024) Decision Implementing SB 520 Regarding Standards for POLR:
[Publish Date] Agenda Date: 7/16/2026

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

The CEC adopted the LMS Regulations on October 12, 2022, in docket 21-OIR-03. b. Potential Impact on Pioneer
i. The LMS rules include compliance obligations for large CCAs, like Pioneer. These compliance obligations include submission of an LMS plan and to consider adopting real-time rates. Although Pioneer's public position is that the CEC does not have authority over CCA rates, Pioneer will continue to make all reasonable efforts to comply with LMS as a show of good faith cooperation with California policies regarding dynamic rates.
c. Key Issues
i. Ensure implementation of the LMS regulations is fair and equitable to CCAs, and ii. in accordance with the regulations
iii. Ensure that the CEC respects CCA autonomy in setting their own rates iv. Ensure Pioneer maintains compliance with CEC mandates and requirements d. Status Update
i. April 9, 2026 – The CEC issued an Order Instituting Rulemaking to evaluate improvements to implementation of the LMS and expand participation among ratepayers and third-party service providers.
e. Background Documents/ Key Decisions
i. Load Management Standards: https://www.energy.ca.gov/programs-and-topics/topics/load-flexibility/load-management-standards ii. Pioneer Revised Load Management Standard Plan:
https://efiling.energy.ca.gov/GetDocument.aspx?tn=266073&DocumentContentId= 103090
[Publish Date] Agenda Date: 7/16/2026

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

Submit annual reports to CEC demonstrating implementation of the Plan, as approved by the Board.
v. July 1, 2027: Offer each Pioneer customer voluntary participation in either a marginal cost-based rate, if such rate is approved by Pioneer’s Board, or a cost-effective load flexibility program identified in 20 CCR section 1623.1(b)(3). vi. Three years after compliance plan approval (December 8, 2028) and triennially thereafter: Review the Plan at least once every 3 years after the Plan is adopted by the Pioneer board. Submit any updates of the Plan to the Board if there is a material change.
g. Pioneer Lead: Braden Henderson
• Power Charge Indifference Adjustment (PCIA) – R.25-02-005:
a. Proceeding Overview
i. This proceeding will consider the rules and processes related to the Energy Resource Recovery Account (ERRA) and PCIA, which are the mechanisms by which unbundled customers are assessed the costs for generation resources procured by the IOUs on their behalf. The Commission bifurcated the proceeding into two tracks - Track One is an expedited consideration of modifications to the market price benchmark (MPB) calculations and Track Two will be a more holistic review of potential changes to the ERRA and PCIA, potentially including, for example, sunsetting or re-vintaging resources, changes to Bundled Procurement Plans (BPPs), and incorporation of slice of day.
b. Potential Impact on Pioneer
i. In the recent ERRA forecast cases, the PCIA has been negative for certain vintages of unbundled customers, meaning they will see a credit on their bill for the value of IOU resources procured on their behalf. This has drawn the scrutiny of the IOUs, ratepayer advocates, and the CPUC, resulting in a reassessment of certain components of the PCIA calculation, particularly the RA MPB, which, given current high RA prices, has contributed to the negative PCIA. Changes to the Market Price Benchmarks (MPBs), and PCIA methodology in general, could result in shifting costs for IOU generation resources from bundled to unbundled customers. On the flipside, the wholistic nature of Track 2 provides an opportunity to fundamental revisit the PCIA structure and propose solutions to help limit exposure for CCAs and prevent unfair cost shifts between bundled and unbundled customers. c. Key Issues
[Publish Date] Agenda Date: 7/16/2026

i. Track 1
• Revisions to the RA MPB, which is an element of the value attributed to PCIA resources.
ii. Track 2
• How to value renewable energy certificates (REC) generated prior to January 1, 2019, and used for bundled service customer compliance, for the purpose of calculating the PCIA (Pre-2019 Banked RECs)
d. Status Update
i. December 1, 2025 - the California Community Choice Association (CalCCA) filed a Writ of Review (Writ) appealing a decision by the California Public Utilities Commission (CPUC) that will result in a shift of hundreds of millions of dollars from unbundled to bundled customers via the Power Charge Indifference Adjustment (PCIA). In its Writ, CalCCA explains that the CPUC’s arbitrary decision to change the PCIA methodology and apply that change 2025 rates violates the longstanding prohibition against retroactive ratemaking, which is intended to ensure customer certainty and stability in rates. Before the Court of Appeals determines whether to take up the appeal, the CPUC will have an opportunity to respond to the Writ and CalCCA will reply to the CPUC response.
ii. March 2, 2026 – CalCCA submitted testimony on the Pre-2019 Banked RECs issue which:
• Explains how the PCIA framework operates to ensure statutory indifference between bundled and unbundled customers, including how REC value is conveyed to customers;
• Demonstrates that Later Departing Customers paid for their share of Pre-2019 Banked RECs when those RECs were generated but have not received the value of those RECs when they are later used for Current Bundled Customer RPS compliance;
• Shows that failure to credit Later Departing Customers when Pre-2019 Banked RECs are used for Current Bundled Customer compliance results in a cost shift from Current Bundled Customers to Later Departing Customers; • Recommends that Pre-2019 Banked RECs be valued at the current RPS MPB – the avoided cost of procuring new RECs in the market – when used for Current Bundled Customer compliance, with the full value recorded as a vintage-specific credit to the PCIA corresponding to the year the RECs were generated; • Explains why vintage-specific crediting ensures only the correct customer vintages receive the correct values and prevents double compensation; • Concludes that CalCCA’s proposal is consistent with Commission precedent, maintains statutory indifference, and can be implemented within the existing PCIA framework; and that
• In the absence of valuation, the Commission is required pursuant to Public Utilities Code section 366.2(g) to provide an allocation to Later Departing Customers for their share of RECs used by the IOU of Pre-2019 Banked RECs, which could be achieved by reducing the Net RPS Procurement Need as measured on the Commission’s Renewable Net Short Calculation template for the LSEs serving those Later Departing Customers.
[Publish Date] Agenda Date: 7/16/2026

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

f. Key Dates
i. Track one is completed at the regulatory level but could be revisited depending on the outcome of the appeal brought by CalCCA.
ii. Track 2:
• May 12, 2026 – Testimony on Staff Report
• May 22, 2026 – Rebuttal Testimony on Staff Report
• May 26, 2026 – Deadline to Present Settlement on Track 2 Issues or a Motion to Request Hearings
• May 27, 2026 – ALJ Ruling on the Need for Hearing
• June 2, 2026 – Evidentiary Hearing, if needed
• June 16, 2026 – Track 2 Opening Briefs
• June 25, 2026 – Track 2 Reply Briefs
• By August 17, 2026 – Proposed Decision issues
• September 17, 2026 – CPUC Decision
iii. A schedule for Track three will be established in a forthcoming Scoping Ruling, but it is expected to be a protracted proceeding that extends into 2028. g. Pioneer Lead: Chau Pham
• Safety & Reliability OIR– R.24-05-023:
a. Proceeding Overview
i. This is a multi-track rulemaking to consider changes to policies related to safety, reliability, and resiliency of electric distribution systems. The near-term focus of this proceeding will develop processes for how the investor-owned utilities will collect and aggregate data to establish a foundation for measuring utility outages. b. Potential Impact on Pioneer
i. This proceeding is closely related to Public Safety Power Shutoff (PSPS) and Enhanced Powerline Safety Setting (EPSS) events which are of critical concern to Pioneer and its customers. Pioneer is likely to support:
• Transparency on the cause of outages to customers.
• Alternative approaches to reduce EPSS and PSPS events. • Protecting customers from increased costs while increasing reliability. c. Key Issues
i. The focus of the Rulemaking is to evaluate the safety, reliability, and resiliency of the electric distribution system. A major component of the rulemaking are outage events. The IOU’s planned outages are from scheduled maintenance, PSPS, and rotating outages during heatwaves. The IOU’s unplanned outages occur due to damage to equipment, EPSS, and by first responder request. PSPS and EPSS events are of particular concern for vulnerable areas; PSPS events have seemingly reduced in recent years but have been replaced with EPSS events. Overall, total outages events have been increasing since 2015, while outage duration peaked in 2019, outages are now leveling out or trending downward.
[Publish Date] Agenda Date: 7/16/2026

d. Background Documents/ Key Decisions
i. R.18-12-005, OIR to Examine Electric Utility De-Energization of Power Lines in Dangerous Conditions, Scoping Ruling (Mar. 08, 2019):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M270/K419/270419337.PDF ii. R.18-04-019, OIR to Consider Strategies and Guidance for Climate Change Adaptation, Scoping Ruling (Oct. 10, 2018):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M231/K128/231128764.PDF iii. R. 21-06-017, OIR to Modernize the Electric Grid for a High Distributed Energy Resource Future, Scoping Ruling (Nov. 15, 2021):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M422/K949/422949772.PDF e. Status Update
i. December 15, 2025 - The three IOUs submitted a Draft Customer Reliability Report Template. The report proposes to submit annual reporting of safety and reliability metrics leveraging a narrative reporting format. The submission identifies new metrics to report but the draft likely requires additional clarification on terms and metrics. Pioneer's joint party to file reply comments requesting further clarification. ii. January 26, 2025 - Pioneer's joint party has filed reply comments requesting further clarification on the IOU’s proposed metrics. The party has advocated for the IOUs to provide meaningful analysis within future reports on how customers are being impacted by outages including PSPS and EPSS events.
f. Key Dates
i. Joint IOU Report Template – December 15, 2025
ii. Opening Comments – January 9, 2026
iii. Reply Comments – January 26, 2026
iv. Proposed Decision - No later than 90 days after final submissions v. Final Decision - No sooner than 30 days after Proposed Decision g. Pioneer Lead: Braden Henderson
• Disconnections – R.18-07-005:
a. Proceeding Overview
i. Rulemaking 18-07-005 was opened in response to Senate Bill (SB) 598 to address disconnection rates for both California’s electric and gas investor-owned utilities. SB 598 requires the commission to prohibit disconnecting service for nonpayment by a residential customer dependent on life-support equipment, who is willing to enter into an amortization agreement, and who satisfies certain other conditions. The ruling was structured to occur in two phases; the first phase for immediate solutions to reduce disconnections, while the second phase is to evaluate the first phase results and establish long term solutions.
ii. This proceeding requires the IOUs to administer two pilot programs Arrearage Management Plan (AMP) and Percentage of Income Payment Plan (PIPP). The pilot programs are reaching the end of their initial period and are being evaluated for continuation.
b. Potential Impact on Pioneer
[Publish Date] Agenda Date: 7/16/2026

i. Pioneer participated in the AMP program and we may have recommendations on how this program may be improved in the event of renewal. Pioneer likely supports programs that offer assistance to low-income customers or customers facing hardship.
c. Key Issues
i. Disconnections in this proceeding are focused on the event when a utility intentionally disconnects a customer, mainly residential customer nonpayment.

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

CalCCA supports continuation of AMP, PIPP, and the current disconnection caps. The IOUs’ opening comments focus on modifying the disconnection caps to allow for more disconnections, sunset of the PIPP program, and refinements to the AMP program. Most parties are in favor of extending the AMP program and do not support continuation of the PIPP program.
iii. April 01, 2026 – Reply comments were filed in response to the comments on the commission’s rule setting workshop. All parties largely hold the positions they established in their opening comments. With most parties in favor of continuation of the AMP program, a successor proceeding is expected to result from this proceeding to have a venue for evaluating the ongoing implementation of AMP and other customer protections.
iv. June 5, 2026 – Two Public Participation Hearings (PPH) on disconnections will be hosted by the Joint IOUs. The PPHs are both scheduled to occur on August 6, 2026; the first will begin at 2pm and the second will begin at 6pm. Additionally, comments on TURN's proposal to lower the temperature threshold for suspending service disconnections from 100 degrees Fahrenheit to 90 degrees Fahrenheit are due June 10, 2026.
v. June 22, 2026 – A Draft Resolution was issued refining the previous regulation which prevented IOUs from disconnecting customers when the 72-hour temperature look ahead is predicted to be above 100 degrees or below 32 degrees Fahrenheit. The new resolution revises the upper threshold based on a heat index, specifically CalHeatScore (CHS) Level 2. CHS Level 2 roughly equates to 94 to 98 degrees Fahrenheit depending on the region’s humidity.
f. Key Dates
i. Opening Comments – June 10, 2026
[Publish Date] Agenda Date: 7/16/2026

ii. Public Participation Hearing – August 6, 2026
iii. Statutory Deadline – December 31, 2026
g. Pioneer Lead: Braden Henderson
• High-DER Future – R.21-06-017:
a. Proceeding Overview
i. The High Distributed Energy Resource (DER) proceeding is the rulemaking in alignment with the CPUC’s Distributed Energy Resources Action Plan 2.0 which aims to leverage DER planning to help achieve California’s renewable energy targets in the 2022-2026 timeframe. The proceeding is currently conducting Track Two and Track Three.
b. Potential Impact on Pioneer
i. This proceeding’s issues include energization of new customers and distributed resources. Other CCAs (i.e., Redwood Coast Energy Authority) have faced some challenges with the interconnection of loads in their service territory, however DER interconnection may not be a priority concern for Pioneer at the moment. ii. This proceeding is actively evaluating impacts to the distribution grid for increased electric loads from emerging technology such as electric vehicles. In parallel demand response policy and changes to time-of-use (TOU) rates from shifted loads may be of concern to Pioneer.
c. Key Issues
i. For Track Three, the main priorities are grid modernization investments in the near term, the implementation of smart inverters to utilize advanced functionalities for grid services, and the better alignment of planned infrastructure investments with utility distribution planning. Overall, this effort seeks to plan for high penetration of DERs and electrification to drive down costs over time. ii. The commission has resurfaced Track Two of this proceeding. Track Two, focused on the topic of DER Orchestration, was discussed earlier in the proceeding without any resulting decisions or consensus. The Commission is exploring how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value added services.
d. Background Documents/ Key Decisions
i. R. 14-08-013 – OIR Regarding Policies, Procedures and Rules for Development of Distribution Resources Plans, Scoping Ruling (Jan. 26, 2016):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M157/K902/157902794.PDF e. Status Update
i. January 2, 2025 – CalCCA submitted reply comments in response to the IOU’s electrification studies and opening comments to emphasize that the IOUs should reevaluate their assumptions and prepare updated analysis that reflects realistic use of demand flexibility programs. Included in this is also recommending the IOUs roll out pilot programs to better understand realistic adoption rates; PG&E agreed with CalCCA on this topic in their reply comments.
ii. February 6, 2026 – Following the completion of the IOU’s electrification studies, the assigned commissioner has issued a ruling defining the schedule for Track Three to include an All-Party Workshop, Workshop Report, and Party Comment. [Publish Date] Agenda Date: 7/16/2026

iii. March 23, 2025 – The assigned commissioner issued a ruling requesting comments on how IOUs, as the Distribution System Operators (DSOs), can create a DER Orchestration framework to enable value added services. Opening comments are expected to question if IOUs are the appropriate parties to operate DER markets, and if there were to be the operators, what guardrails are required. iv. April 20, 2026 – Parties filed opening comments in response to the Track 1 and Track 2 issues regarding orchestration of DERs. Most parties support the objective to implement DER orchestration. However, there is concern from non-IOU parties that the Commission should first establish policies and processes before determining implementation pathways. The Commission also released the schedule for the 2026- 2027 Distribution Planning and Execution process.
v. April 30, 2026 – Parties filed reply comments in response to the Track 1 and Track 2 issues regarding orchestration of DERs. The IOUs specifically replied in opposition to CalCCA’s comments which raised the concern that the IOUs are prematurely being recognized as the DSO. However, many other parties’ reply comments underscore that there are foundational concerns with the proceeding assuming the IOUs as the lead DSO.
vi. May 8, 2026 – The Commission issued a ruling requesting comments and reply comments on the use of the IOUs second Electrification Impact Studies (EIS2) in their yearly Distribution Planning and Execution Process (DPEP). vii. May 29, 2026 – Parties submitted opening comments on if the Commission should require the IOUs to use the EIS2 analysis in their yearly DPEP. The majority of parties commented that the EIS2 is not appropriate for the DPEP because either the methodology needs improved or that the appropriate procedure to factor load growth is through the CEC's IEPR process.
viii. June 5, 2026 – Parties submitted reply comments regarding the use of EIS2 in DPEP.

While IOUs generally echoed that most parties agree that the studies are too limited to apply to the DPEP, a few parties call for action to be taken to address the lack of DER market and resulting lack of flexible resource use in distribution planning. ix. 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.
x. July 9, 2026 – The ALJ released two Track 2 Workshop Reports on “Distribution System Operator DER Orchestration” and “TSO [Transmission System Operator] - DSO Coordination.” The ALJ has requested comments and reply comments on a set of questions related to how to best establish an IOU-lead DSO DER orchestration program.
f. Key Dates
i. Issuance of Assigned Commissioner Proposal on Track 3 Issues – July 7, 2026 ii. Issuance of ALJ’s Questions on Track 2 Workshop Reports – July 9, 2026 iii. Track Three Opening Comments – July 21, 2026
iv. Track Two Opening Comments – July 27, 2026
v. Track Three Reply Comments – July 28, 2026
[Publish Date] Agenda Date: 7/16/2026

vi. Track Two Reply Comments – July 31, 2026
vii. Proposed Decision on Track 3 – Quarter 3 of 2026
g. Pioneer Lead: Braden Henderson
• Distributed Energy Resources – R.22-11-013:
a. Proceeding Overview
i. The Commission issued OIR 22-11-013 to achieve consistency of cost effectiveness assessments, improve data access and use, and consider equipment performance standards for DER customer programs.
b. Potential Impact on Pioneer
i. The CPUC uses the Avoided Cost Calculator (ACC) to determine the primary benefits of DER across Commission proceedings. Pioneer may be inclined to follow this proceeding as the ACC calculates various costs related to items such as generation capacity, energy, and RPSs that may have an impact on electricity rates, portfolio planning, or DER program administration.
c. Key Issues
i. Currently in Phase I, the proceeding covers DER program cost-effectiveness issues, data access and use, and equipment performance standards. All of the latest updates and decisions related to the ACC fall under this proceeding. d. Background Documents/ Key Decisions
i. R.14-10-003 OIR to Create a Consistent Regulatory Framework for the Guidance, Planning and Evaluation of Integrated Distributed Energy Resources, Scoping Ruling (Jan. 5, 2015):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M143/K990/143990275.PDF e. Status Update
i. March 4, 2026 – The assigned commissioner issued a ruling setting the scope and schedule for Phase Three. Phase Three will be exploring the development and application of the ACC's Guiding Principles.
ii. April 29, 2026 - CPUC staff prepared a proposal on their proposed updates to the 2026 Avoided Cost Calculator. Staff also presented the proposal at a public workshop. At a high level, the proposed updates are to apply a single value to green house gas (GHG) emission reductions capped at the societal cost of carbon. iii. June 5, 2026 – CPUC staff revised the 2026 Avoided Cost Calculator Staff Proposal, and set the schedule for comments to be submitted. The revised proposal further defines that the single value for avoided costs will be based on the RESOLVE GHG shadow price.
f. Key Dates
i. Revised Staff Proposal – June of 2026
ii. Opening Comments – June 19, 2026
iii. Reply Comments – June 26, 2026
g. Pioneer Lead: Braden Henderson
[Publish Date] Agenda Date: 7/16/2026

• Distributed Energy Resource Interconnections (Rule 21) – R.25-08-004:
a. Proceeding Overview
i. The purpose of this proceeding is to update and improve Rule 21 and associated interconnection procedures concerning the safety and reliability of the electric grid as distributed technologies continue to evolve, promote greater transparency and certainty around interconnection processes, and to contain costs for all ratepayers that use the electric grid.
ii. This proceeding will be conducted in multiple phases. Phase 1 will address issues related to Screens Q and R, interconnection timelines, and the interconnection process and fees for resources that are not interconnecting under the Net Billing Tariff (NBT) or Net Energy Metering (NEM) Tariff.
b. Potential Impact on Pioneer
i. Phase 1 of this proceeding is expected to impact how effectively and efficiently resources can be interconnected through Rule 21. Changes to Rule 21 may impact Pioneer’s ability to procure resources as well as implement programs. Delays in Rule 21 interconnections can have serious impacts to developer’s ability to cost effectively deploy resources, including biomass generation for Pioneer to procure.

Changes to how residential scale resources are interconnected can also affect future programs Pioneer may wish to administer.
c. Key Issues
i. The primary issue discussed in Rule 21 has been related to Screen Q, costs for interconnection studies, and timeline for interconnection applications. Most stakeholders agree that Screen Q is ineffective as almost all larger projects fail Screen Q and are then required to conduct lengthy and costly interconnection studies. Technology developers are in favor of having a faster and less costly process for interconnecting non-export DER technologies such as backup battery systems.
d. Background Documents/ Key Decisions
i. R.11-09-011 – OIR to Improve Distribution Level Interconnection Rules and Regulations, Scoping Ruling (Jun. 20, 2012):
https://docs.cpuc.ca.gov/PublishedDocs/EFILE/RULC/169188.PDF ii. R.17-07-007 – OIR Streamlining Interconnection of Distributed Energy Resources and Improvements to Rule 21, Scoping Ruling (Oct. 2, 2027):
https://docs.cpuc.ca.gov/PublishedDocs/Efile/G000/M196/K476/196476255.PDF e. Status Update
i. January 26, 2026 - Pioneer submitted a motion for party status to participate in this proceeding. Our primary interest will be to ensure that bioenergy resources are included in any reforms of the Rule 21 interconnection process, including reforms to address the current delays in interconnecting resources. A scoping memo providing the scope of issues and schedule for the proceeding is expected in the coming weeks.
ii. March 3, 2026 – The assigned commissioner released a scoping memo for Phase One. Phase One is prioritizing issues related to Screens Q & R, interconnection timelines, and the process for resources not interconnecting through the Net Billing 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 [Publish Date] Agenda Date: 7/16/2026

BioMAT program. Pioneer has been accepted as a party to the proceeding and will submit comments supporting changes to improve IOU compliance with interconnection timeline requirements.
iii. April 30, 2026 - Parties submitted opening comments regarding updates to Rule 21.

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

Most parties expressed support for reevaluating the screening criteria for Rule 21, largely around Screen Q.
iv. May 29, 2026 – Parties submitted reply comments regarding the potential for Rule 21 updates. Reply comments were generally reflective of each party’s opening comments.
f. Key Dates
i. Opening Comments to Phase One Scoping Memo – April 30, 2026 ii. Reply Comments to Phase One Scoping Memo – May 29, 2026 g. Pioneer Lead: Braden Henderson
1 Attachment 3: Communications, Outreach & Customer Care Updates Date: 7/23/2026
NOTABLE ACHIEVEMENTS – MAY 2026
• News of Pioneer’s pre-pay bond transaction captured significant earned media attention, with Pioneer mentions in national and international publications. CEO Don Eckert provided background briefings to Bloomberg News and International Finance Review. • Pioneer had a strong showing at both the El Dorado and Placer County fairs. With good booth placements and well-placed signage, staff was on hand to talk to customers and share prizes. • Pioneer remains the top rated CCA on Google, with 4.2 stars and 147 reviews. Comparatively, the closest two CCAs each have 3.5 stars; the CCA with the closest total reviews has 45 and a 2.7 rating. (One year ago, Pioneer was the fifth ranked CCA with a 3.1 rating and 61 reviews.)

WEBSITE
Interest in programs continues to drive website traffic, with the top five pages visited being:
1) PowerShift Rewards
2) Home
3) AC Tune-Up Rebate
4) GridGen
5) Incentive Finder
The strong traffic is attributed to a combination of factors including paid advertising, email, and media coverage. The Pioneer website averaged nearly 500 users per day in June.

PIONEER IN THE COMMUNITY
Increased engagement with expansion communities and maintaining a strong presence in current member communities made for a busy June.
• Outreach to all 16 expansion communities to schedule in-person presentation on expansion planning
• Tuolumne County Board of Supervisors in-person presentation on expansion and community partnership in 2027 leading up to service launch
• City of Live Oak in-person presentation to City Council • Met with Sonora City Administrator to discuss expansion • Met with Tuolumne County Supervisor Brandon and coordinated a request for meeting with Pioneer’s procurement team
• Met with Yuba City City Manager to discuss language translation needs • Hand delivered PCIA Offset Credit letters to top customers to familiarize them with the credit appearing on bills and reinforce Pioneer’s commitment to rate competitiveness • PCIA follow-up with Marshall Medical
• Hosted successful Community Benefit Grant webinar for area non-profits • Sponsored and attended the Sierra College Workforce Summit • Participated in the Regional Economic Development Stakeholders meeting Plf)NEER

COMMUNITY ENERGY
SPONSORED BY: Plf)N EE R

COMMUNITY ENERGY
Page View by Screen June
4500
4000
3500
3000
I 2500
2000
I I 1500
1000
500
PowerShift Home AC Tune Up GridGen Incentive Finder

• Attended South Placer Rotary meeting
• PG&E Quarterly North Valley and Sierra Region meeting • Yuba Sutter Chamber Government Affairs Committee meeting • Attended and presented at the Loomis Chamber meeting
• Attended the El Dorado Chamber Business Showcase
• Attended Feeding the Foothills Volunteer Appreciation event • Sponsorship of Forget Me Not Dinner, Auburn
• Participated in regional Joint Government Relations Committee meeting • Lunch sponsorship and presentation at El Dorado County Chamber of Commerce luncheon • Sponsorship and booth presence at El Dorado County Fair • Sponsorship and booth presence at the Placer County Fair • Colusa Indian Energy meeting and follow-up call with Pioneer’s procurement team • Sponsorship of Rods and Relics Car Show
During the first six months of the year, staff made 219 direct connections with current and expansion members, with 108 engagements with expansion members. Meetings were driven largely by efforts to promote programs like Clean Fleet Revenue and Solar RECS; additional background briefings and information about how we would like to partner; and requests for photos for roll-out marketing efforts.

CUSTOMER CARE
Call Center
Call Stats
• 328 calls (down 26% from May)
o Billing inquiry was the most frequent topic at 15.42% o NEM was the second most frequent topic at 11.74%.
o Highest volume of calls was on 6/5 possibly because we called a PowerShift Rewards event the day before.
• 68 surveys completed with a 91.2% satisfaction rate
Chatbot
• 303 interactions
• 102 live conversations, with average duration being 24 minutes, 45 seconds • Customer satisfaction rating of 4.8/5

PAID ADS PROMOTE PROGRAMS
Pioneer currently is running paid ads to support the seasonal AC Tune-Up Rebate and PowerShift Rewards programs, as well as the GridGen program. Ads are running on local sites, digital display, Meta, mobile ad messenger and search displays. Local site display ads, weather-targeted digital, and mobile ads are performing above industry benchmarks and contributing to increased website traffic and program participation.

SOCIAL MEDIA MAINTAINS STRONG POSITIVE SENTIMENT
Pioneer’s community engagement and its presence at the El Dorado and Placer County fairs generated increased engagement on social media throughout June, with 86,000 impressions across all social pages.

Sentiment remains positive. Collaborative posts, especially those by Placer County, drove visitors to our social channels (Facebook, Instagram, LinkedIn). Paid social ads also contribute to positive engagement and increased following, with LinkedIn having the highest number of new followers in June.

Top performing posts:

Pioneer sponsorship of
Community Stage at Placer
County Fair:

Savings Tip Tuesdays remain
popular
News of pre-pay bond
transaction shared by CCCFA,
CalCCA and others

EARNED MEDIA
News about Pioneer’s pre-pay bond deal captured significant earned media attention, with Pioneer mentions in national and international publications – largely due to the participation of Alphabet (Google), introducing Pioneer to new media audiences.

OUTLET TOPIC CONTENT AUDIENCE
REACH
Cap Public Radio What’s Really Going On With
Tahoe’s Power Situation?
Interview with CEO Don
Eckert

16.9K
KXJZ South Lake Tahoe/Liberty
Utilities
Interview with CEO Don
Eckert
115.3
Podcast: Insight with
Vicki Gonzalez
Tahoe Utility Searches for New
Power Supplier
(Rerun of Cap Public
Radio story)

11.8 International
Financing Review
(Pre-pay transaction) Background interview
with CEO Don Eckert
My Mother Lode Tuolumne County Supervisors
To Hear About Pioneer Energy’s
Plans
Promote Pioneer’s
presentation

12.5 Bloomberg Large Prepaid Energy Deals
Poised to Hit Booming Muni
Sector
Interview with CEO Don
Eckert

5.5M
Bond Buyer Google parent Alphabet taps
muni market in first for
hyperscalers
Mention as part of pre-pay bond2.7K
Rolling Out Why Alphabet’s $1B energy
deal is brilliant for Google stock
Mention as part of pre-pay bond14.7
Yahoo Finance Alphabet Uses New Financing
Playbook to Support AI Power
Demand
Mention as part of pre-pay bond
(f) ::~~~ommunity Energy
2w 0 Ed,tN1 ,($)
Pioneer Community Energy is proud to be a part of a transaction that highlights the growing role of CCAs in developing creative solutions that enhance energy affordability. strengthen long-term reliability. and deliver lasting value to local communities.

At California Community Choice Association
ij~ 5,286 lollowers 3w ,(S)
• Pioneer Community Energy and the California Community Choice Financing Authority (CCCFA) are making headlines in the municipal fin aoce world.

A planned S 1 billion prepaid energy transaction would help Pioneer secure a long-term supply of discounted electricity for its customers. The deal has also attracted national attention due to the participation of Alphabet Inc. (Google's parentcompany)asthefunding recipient
+ The transaction highlights how community choice providers are leveraging innovative financing structures to support long-term energy affordability and reliability for the communities they serve.

Read more here: https://lnkd.in/ eKMNjkBG
Al Funding Boom Reaches Muni Market With Google-Tied Oeal financialpost.com
c• 1.mda Praseudsuk and 9 others 2reposts

Ad Hoc News
(Germany)
Alphabet Taps Muni Bond
Market for $1 Billion as AI
Energy Needs Surge
Mention as part of pre-pay bond21.2K
BigGo Finance Alphabet Upsizes Equity Raise
to $84.75 Billion, Setting a
Historic Mark in the AI
Infrastructure Race
Mention as part of pre-pay bond(online new
– reach not
published)
YubaNet Grass Valley and Nevada City
Celebrate America’s 250th with
a Hometown Celebration for
Every Generation
Parade sponsorship 23.4K
Midnight Trader Live Alphabet's Municipal Bond
Debut Draws Strong Investor
Demand
Mention as part of pre-pay bond1.1K
Markets Business
Insider
Alphabet’s (GOOGL) $1 Billion
Muni Bond Deal Puts Big Tech’s
AI Power Needs in Focus
Mention as part of pre-pay bond554.5K

Attachment 4: Program Updates
Date: 7/23/2026

PROGRAMS SUMMARY
Pioneer Program Page
• Reconfiguring the Programs Webpage to include more featured programs for our customers • Enhancing partnership and coordination efforts with NREN (Northern Rural Energy Network) to promote rebates & incentives to our customers
Strategic Energy Management (SEM) Pilot
• Program proposal for board review
• Energy efficiency program targeted for large C&I, Ag, Municipal organizations • Implementation partner will act as liaison between customer and energy rebates, educational materials, and energy efficiency environments
AC Tune-Up
• Program launched on April 1st
• 868 applications received since launching on April 1st, more than doubling the number of applications received during the same time period of 2025
• Pioneer’s new customer portal, designed to make it easier for customers to track their application status and for staff to track program data, is running effectively. o More than 45% of this year’s applications have been received though the portal PowerShift Rewards
• 2026 season launched on May 1
• 2,644 customers are currently enrolled
• 3 events called in June
GridGen
• 58 projects completed and received final inspection
• 53 projects completed and received Permission to Operate • 124 customers in the active pipeline
• 535.1 KW of solar capacity installed
• 407,170.82 kWh of clean energy generated since program launched • Federal rebates for commercial customers expire on July 4, 2026 Incentive Finder
• 2,530 searches since January 2026
• Data shows that customer interest in HVAC, home appliance, battery and insulation rebates is strong • Future development of a Commercial Incentive Finder
Hourly Flex Pricing Pilot
• Annual true-up period begins in August, after 12 consecutive months of service • Two customers enrolled in the program (19 meters/accounts) LED Discount Lighting
• 29 local retailers are currently participating, including one national partner (Lowe’s) • Nearly 100,000 units of inventory sold since program launch • Program remains very popular with customers and retail partners Ice Energy
• No updates.

Plf)NEER

COMMUNITY ENERGY
Projected Status Through Fiscal Year 2025-26
This Completes the Second Year of the Three Year Plan

OVERALL PERFOMANCE TOTAL
Objectives by Status 19 3 0 0 22
Tasks by Status 45 1 0 4 50

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
KEY
Within 15% of target = "On Target"
Within 30% of target = "Off Target"
Grey = Not Started
Greater than 30% of target - "Critical"
Info. Technology
Finance & Administration
Human Resources
Human Resources
Human Resources
All Departments
I.T. & Communications
Finance & Administration
Communications
Communications
Power Supply & Leg/Reg
Power Supply
Communications
Finance
Finance
Administration
Power Supply
Finance & Administration

PIONEER COMMUNITY ENERGY STRATEGIC PERFORMANCE SUMMARY
Goal Owner
Communications
Programs
Programs
Leg & Reg
- - - -
- - - -
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-

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 Not Started

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 Communications Not Started Finance
Administration
Administration
Communications
Communications
Communications
Finance
Finance
Finance
Administration
Administration
Communications
Legislative & Regulatory
Legislative & Regulatory
Legislative & Regulatory
Communications
Communications
Administration
Communications
Communications
Communications
Communications
All Departments
Power Supply
Power Supply
Power Supply
Goal Owner
Communications
Programs
Communications
Programs
Programs

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 KEY
Within 15% of target = "On Target"
Within 30% of target = "Off Target"
Grey = Not Started
Greater than 30% of target - "Critical"
Information Technology
Administration
Finance
Human Resources and Finance
Administration
Power Supply and Leg & Reg
Power Supply
Power Supply
Power Supply
Information Technology
Human Resources
Administration
Human Resources
All Departments
Human Resources
Human Resources
Human Resources
Communications
Achievements Past Quarter (April through June 2026)

1. Adoption of FY 2026-27 Budget that supports Pioneer’s investment grade credit rating.

2. Closed on six BioMAT Power Purchase Agreements with two of the projects within Pioneer’s territory.

3. Adoption of the Power Charge Indifference Adjustment bill credit to retain Pioneer’s largest accounts.

4. Adoption of the 2026 Legislative Platform.

5. Exploration of expansion into the City of South Lake Tahoe.

6. Volunteer event at Feeding the Foothills.

7. Closed on the Prepay Bond transaction that received national attention and will generate approximately $70 million in power supply savings over the next nine years.

8. Issued approximately $1 million in checks or bill credits to our solar customers for net generation.

9. Pioneer was a co-host of the 2026 CalCCA Annual Conference in Sacramento.

10. Executed cQuant and Amperon contracts for software services that optimize the power supply portfolio resulting in reduced costs.

Your Power. Your Choice.
2510 Warren Dr., Ste. B Rocklin, CA 95677 | (916) 758-8969 [email protected] | pioneercommunityenergy.org

CELEBRATING
175 YEARS
From the Gold Rush to today, Placer
County has been defined by vision,
innovation, and a commitment to
building a brighter future.

Through strong leadership, bold
ideas, and a spirit of collaboration,
this region continues to create
opportunity, strengthen communities,
and drive economic growth.

We are grateful to be part of that
journey and proud to serve the
businesses, residents, and leaders
shaping the next chapter of Placer
County’s success.

Happy 175th anniversary,
Placer County.

OF PROGRESS, COMMUNITY,
AND INNOVATION.

Plf)NEER

COMMUNITY ENERGY
Page | 1
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.

Plf)NEER

COMMUNITY ENERGY
Page | 2
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.

Page | 3
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.

Page | 4
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.

Page | 5
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.

Page | 6
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.