Pioneer Community Energy Board of Directors
September 18, 2025

to Consultant Services Agreement
369617.3

EXHIBIT A

SCOPE OF SERVICES
Consultant will provide the following services:

1. Program Development & User Experience:
• Develop incentive finder tool with core design for use on Pioneer’s online platform, ensuring it is integrated with Pioneer's existing tools and provides a user-friendly experience. • Develop tool in conjunction with Pioneer and in a complementary format to existing Pioneer programs and website tools.
• Create an intuitive, engaging, and seamless online experience to guide users and assist in identifying and utilizing available cost saving incentives choices, including customized recommendations and streamlined search functions.

2. Resource Identification & Personalization:
• Develop tool centered around enabling users to find relevant cost savings information, incentives, and products, and to customize this information to their specific needs and circumstances.
• Manage brandable search engines for federal, state, and local incentives, and continuously maintain resources to ensure funding and availability is current. • Personalize and tailor customer incentive information. • Direct income-qualified (or otherwise eligible) customers to available no or low-cost programs.
• Help users filter search results to narrow down incentives and/or programs of interest and email the results to themselves without needing to set up accounts or provide personally identifiable information.
• Provide a marketplace with daily analysis of thousands of products in multiple categories to provide optimal options for customers.
• Allow users to compare deals across incentive programs and monitor trends, with alerts for eligibility, price drops or updates, as appropriate.

3. Financial Assistance & Application Support:
• Help customers mitigate financial barriers and navigate the application process for available incentives, rebates, and funding.
• Facilitate identifying available financing options with no upfront costs and/or low monthly payments for energy efficient appliances, ensuring a hassle-free, federal, state, and/or locally approved application process.
• Help customers unlock instant rebates from utilities, governments, and top brands to lighten financial load, save money and promote sustainable living. • Provide a direct link to the program's application or information page for every incentive or program, as available.
• Assist customers with prioritizing rebate programs that offer the highest return, fewest application hurdles, and available funding at the time of application. • Assist customers in applying for funding.

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4. Ongoing Program Administration & Support:
• Develop necessary capacity for the continuous operation, maintenance, tracking, and promotion of the program, ensuring its effectiveness and user satisfaction. • Continually monitor and update all relevant incentive finder tools, resources, and databases to ensure incentives are still available and applicable (e.g., funding, application period, criteria). • Follow up on customer success in obtaining rebates to track specified metrics. • Assist with Pioneer customer escalation matters.
• Assist Pioneer staff in developing appropriate and effective marketing materials to maximize program utilization.

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369617.3

EXHIBIT B

PAYMENT FOR SERVICES RENDERED
Maximum Limit & Fee Schedule
The total amount for services rendered not to exceed $75,000.

The maximum hourly rate shall not exceed $175 per hour.

Fee Summary
Task Rate/Frequency Estimated Hours Cost Annual
Maximum
Incentive Finder
Setup
Flat Rate, One-time N/A $7,500 (one-time) $7,500
Incentive Finder
Use & Maintenance
Monthly Fee,
Billed Quarterly N/A $750/month $9,000
Content Creation Hourly
- Initial effort over two
months of 120 hours
- Ongoing work of 10
hours per month (100
hours in first year)
Not to Exceed
$38,500
$38,500
Additional Work as
Requested
To be Determined To be Determined To be Determined
$20,000
Total Not-to-Exceed Amount: $75,000
Invoices
Invoices shall include a list of work performed by billable hour including date, hours and services provided.

Work performed by Consultant will be subject to final acceptance by Pioneer.

Reimbursable Expenses
Administrative, overhead, secretarial time or overtime, word processing, photocopying, in house printing, insurance and other ordinary business expenses are included within the scope of payment for services and are not reimbursable expenses. Travel expenses must be authorized in advance in writing by Pioneer.

Submit all invoices to: Pioneer Community Energy
Attn: Eric Acedo
[email protected]
2510 Warren Drive, Suite B
Rocklin, CA 95677

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369617.3

EXHIBIT C

FACILITIES, EQUIPMENT, AND OTHER

MATERIALS, AND OBLIGATIONS OF PIONEER
(Specify all equipment and facilities to be provided or made available by Pioneer, and any other Pioneer obligations.)

NOT APPLICABLE

to Consultant Services Agreement
369617.3

EXHIBIT D

HOLD HARMLESS AGREEMENT

AND INSURANCE REQUIREMENTS

1. HOLD HARMLESS AND INDEMNIFICATION AGREEMENT
A. To the fullest extent permitted by law, CONSULTANT hereby agrees to protect, defend, indemnify, and hold PIONEER free and harmless from any and all losses, claims, liens, demands, and causes of action of every kind and character including, but not limited to, the amounts of judgments, penalties, interest, court costs, legal fees, reasonable attorneys’ fees for counsel of Pioneer’s choice, expert fees, and all other expenses incurred by PIONEER arising in favor of any party, including claims, liens, debts, personal injuries, death, or damages to any real or personal property (including employees or property of PIONEER) and without limitation by enumeration, all other claims or demands of every character occurring or in any way incident to, in connection with or arising directly or indirectly out of, the Agreement, CONSULTANT’s performance under this Agreement, or CONSULTANT’S failure to comply with any provision in this Agreement. CONSULTANT agrees to investigate, handle, respond to, provide defense for, and defend any such claims, demand, or suit at the sole expense of the CONSULTANT. CONSULTANT also agrees to bear all other costs and expenses related thereto, even if the claim or claims alleged are groundless, false, or fraudulent. This provision is not intended to create any cause of action in favor of any third party against CONSULTANT or PIONEER or to enlarge in any way the CONSULTANT’s liability but is intended solely to provide for indemnification of PIONEER from liability for damages or injuries to third persons or property arising from CONSULTANT’s performance pursuant to this Agreement. PIONEER’s right to indemnity under this Agreement shall arise immediately upon the occurrence of the event giving rise to the indemnified liability.

PIONEER shall be entitled to a defense under this Agreement immediately upon the institution of a claim or action that is covered by this indemnity, even though liability for said claim or action has not yet been determined at the time the duty to defend the PIONEER hereunder has arisen. CONSULTANT shall not be entitled to any refund of attorneys’ fees, defense costs or expenses in the event that it is adjudicated to have been non-negligent. CONSULTANT shall not be required to indemnify PIONEER for such loss or damage as is caused by the active negligence, sole negligence, or willful misconduct of PIONEER.

B. As used in this section, the term PIONEER means Pioneer or its officers, agents, employees, and volunteers.The term CONSULTANT means Consultant, its officers, employees, servants, agents, or subconsultants, or anyone directly or indirectly employed by either Consultant or its subconsultants, in the performance of this Agreement.

C. The obligations of CONSULTANT set forth herein are not limited by the provisions of any workers’ compensation or similar statute. CONSULTANT expressly waives its statutory immunity under such statutes or laws as to PIONEER.

D. PIONEER does not waive any indemnity rights by accepting any insurance policy or certificate required pursuant to this Agreement. CONSULTANT’s indemnification obligations apply regardless of whether or not any insurance policies are determined to be applicable to the claim, demand, damage, liability, loss, cost or expense.

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E. PIONEER may request a deposit for defense costs from CONSULTANT with respect to a claim. If PIONEER requests a defense deposit, CONSULTANT shall provide it within 15 days of the request.

F. CONSULTANT agrees to obtain executed indemnity agreements with provisions identical to those set forth here from each and every subconsultant or any other person or entity involved in the performance of this Agreement on CONSULTANT’s behalf.

2. INSURANCE:

CONSULTANT shall file with PIONEER concurrently herewith a Certificate of Insurance, in companies acceptable to PIONEER, with a Best’s Rating of no less than A-:VII showing, and complete, certified copies of all required insurance policies, including endorsements affecting the coverage for all policies required by this Agreement. CONSULTANT shall require all of its subcontractors, subconsultants, and other agents to do the same. Approval of the insurance by PIONEER shall not relieve or decrease any liability of CONSULTANT.

3. WORKER’S COMPENSATION AND EMPLOYERS LIABILITY INSURANCE:

Worker’s Compensation Insurance shall be provided as required by any applicable law or regulation.

Employer’s liability insurance shall be provided in amounts not less than one million dollars ($1,000,000) each accident for bodily injury by accident, one million dollars ($1,000,000) policy limit for bodily injury by disease, and one million dollars ($1,000,000) each employee for bodily injury by disease.

If there is an exposure of injury to CONSULTANT’s employees under the U.S. Longshoremen’s and Harbor Worker’s Compensation Act, the Jones Act, or under laws, regulations, or statutes applicable to maritime employees, coverage shall be included for such injuries or claims.

Each Worker’s Compensation policy shall be endorsed with the following specific language:
• Cancellation Notice - “This policy shall not be changed without first giving thirty (30) days prior written notice and ten (10) days prior written notice of cancellation for non-payment of premium to Pioneer Community Energy”.
• Waiver of Subrogation - The workers’ compensation policy shall be endorsed to state that the workers’ compensation carrier waives its right of subrogation against Pioneer, its officers, directors, officials, employees, agents or volunteers, which might arise by reason of payment under such policy in connection with performance under this agreement by the CONSULTANT.
• CONSULTANT shall require all SUBCONTRACTORS to maintain adequate Workers’ Compensation insurance. Certificates of Workers’ Compensation shall be filed forthwith with Pioneer upon demand.

4. ENDORSEMENTS:

Each policy required herein, other than Professional Errors and Omissions and Worker’s Compensation, shall be endorsed with the following specific language:

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A. “Pioneer Community Energy, its officers, agents, employees, and volunteers are to be covered as insured for all liability arising out of the operations by or on behalf of the named insured in the performance of this Agreement.”
B. “The insurance provided by the Consultant, including any excess liability or umbrella form coverage, is primary coverage to Pioneer Community Energy with respect to any insurance or self-insurance programs maintained by Pioneer Community Energy and no insurance held or owned by Pioneer Community Energy shall be called upon to contribute to a loss.” C. “This policy shall not be changed without first giving thirty (30) days prior written notice and ten (10) days prior written notice of cancellation for non-payment of premium to Pioneer Community Energy.”
All endorsements shall be signed by a person authorized by the insurer to bind coverage on its behalf.

5. AUTOMOBILE LIABILITY INSURANCE:

Automobile Liability insurance requirements in this section are only applicable if and when travel is required for CONSULTANT to perform tasks as described in Exhibit A of this agreement.

Automobile Liability insurance covering bodily injury and property damage in an amount no less than two million dollars ($2,000,000) combined single limit for each occurrence.

Covered vehicles shall include owned, non-owned, and hired automobiles/trucks using ISO Business Auto Coverage form CA 00 01 (or equivalent).

6. PROFESSIONAL LIABILITY INSURANCE:

Professional liability insurance which includes coverage for the professional acts, errors and omissions of Consultant in the amount of at least $1,000,000 per occurrence and $2,000,000 aggregate.

The deductible or self-insured retention may not exceed $50,000. If the insurance is on a Claims-Made basis, the retroactive date shall be no later than the Effective Date of the Agreement or commencement of the work. Coverage shall be continued for two years after the completion of the work by one of the following: (1) renewal of the existing policy; (2) an extended reporting period endorsement; or (3) replacement insurance with a retroactive date no later than the commencement of the work under this Agreement. In the event CONSULTANT’s policy is a “claims made” policy only covering those claims made during the policy period, then CONSULTANT agrees to maintain the professional liability insurance required hereunder and with respect to this project in effect for at least three (3) years after acceptance of the work.

7. PRIVACY AND CYBERSECURITY LIABILITY INSURANCE:

Privacy and cybersecurity liability (including costs arising from data destruction, hacking or intentional breaches, crisis management activity related to data breaches, and legal claims for security breach, privacy violations, and notification costs) of at least $5,000,000 US per occurrence.

8. ADDITIONAL REQUIREMENTS:

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369617.3
Premium Payments - The insurance companies shall have no recourse against PIONEER and funding agencies, its officers and employees or any of them for payment of any premiums or assessments under any policy issued by a mutual insurance company.

Policy Deductibles - The CONSULTANT shall be responsible for all deductibles in all of the CONSULTANT’s insurance policies. The maximum amount of allowable deductible for insurance coverage required herein shall be $25,000.

CONSULTANT’s Obligations - CONSULTANT’s indemnity and other obligations shall not be limited by the foregoing insurance requirements and shall survive the expiration of this Agreement.

Verification of Coverage - CONSULTANT shall furnish Pioneer with original certificates and amendatory endorsements or copies of the applicable policy language effecting coverage required by this clause. All certificates and endorsements are to be received and approved by Pioneer before work commences. However, failure to obtain the required documents prior to the work beginning shall not waive the CONSULTANT’s obligation to provide them. Pioneer reserves the right to require complete, certified copies of all required insurance policies, including endorsements required by these specifications, at any time.

Material Breach - Failure of the CONSULTANT to maintain the insurance required by this agreement, or to comply with any of the requirements of this section, shall constitute a material breach of the entire Agreement. In the event any policy is canceled prior to the completion of the Agreement and CONSULTANT does not furnish a new certificate of insurance prior to cancellation, PIONEER has the right, but not the duty, to obtain the required insurance and deduct the premium(s) from any amounts due CONSULTANT under this Agreement.

Subrogation – CONSULTANT hereby waives all rights of subrogation against PIONEER.

CONSULTANT shall additionally waive such rights either by endorsement to each policy or provide proof of such waiver in the policy itself.

Report of Claims – CONSULTANT shall report to PIONEER, in addition to CONSULTANT’s insurer, any and all insurance claims submitted to CONSULTANT’s insurer in connection with the services under this Agreement.

Premium Payments and Deductibles - CONSULTANT must disclose all deductibles and self-insured retention amounts to PIONEER. PIONEER may require Consultant to provide proof of ability to pay losses and related investigations, claim administration, and defense expenses within retention amounts. Ultimately, PIONEER must approve all such amounts prior to execution of this Agreement.

PIONEER has no obligation to pay any premiums, assessments, or deductibles under any policy required in this Agreement. CONSULTANT shall be responsible for all premiums and deductibles in all of CONSULTANT’s insurance policies. The amount of deductibles for insurance coverage required herein are subject to PIONEER’s approval.

Duty to Defend and Indemnify – CONSULTANT’s duties to defend and indemnify PIONEER under this Agreement shall not be limited by the foregoing insurance requirements and shall survive the expiration or termination of this Agreement.

369617.3

EXHIBIT E

CAMPAIGN CONTRIBUTION DISCLOSURE FORM
Local governments are subject to the campaign disclosure provisions detailed in Government Code Section 84308.

Please carefully read the following information to
determine if the provisions apply to you. If you
determine that the provisions are applicable, the
Campaign Disclosure Form must be completed and
returnedtoPioneerwithyourapplication.

No Pioneer Board member or other Pioneer official shall accept, solicit, or direct a campaign contribution of more than $500 from any party1 financial interested
participant,2 or agent3 for 12 months after the Pioneer approves a contract. This prohibition commences when
an application is filed, or a proceeding is otherwise
initiated.

A party to a Pioneer proceeding shall disclose on the record of the proceeding any campaign contribution of more than $500 by a party or agent to any Pioneer member or other Pioneer official during the preceding 12 months. No party to or participant in a Pioneer proceeding, shall make a
contribution of more than $500 to a Pioneer Board member or other Pioneer official during a proceeding and for 12 months after the Pioneer approves a contract. No agent to a party or participant shall make a contribution in any amount to a Pioneer board member or other Pioneer official during the preceding 12 months following the date a final
decision is rendered by Pioneer.

A Pioneer Board member or other Pioneer official who
received a campaign contribution ofmore than $500within the preceding 12 months from any party, or agent, to a
proceeding shall disclose that fact on the record of the proceeding, and shall abstain from participating in the proceeding. However, if he or she receives a contribution that otherwise would require disqualification, and returns the contribution within 30 days of making the decision, or
knowing about the contribution and the relevant proceeding, whichever comes last, , he or she may participate in the proceeding.
1 “Party” is defined as any person who files an
application for, or is the subject of, a proceeding.
2 “Participant” is defined as any person who actively supports or opposes a particular decision in a proceeding.
3 “Agent” is defined as a person who represents a party in connection with a proceeding. If an individual acting as an agent also is acting as an employee or member of
a law, architectural, engineering, or consulting firm, or a similar entity or corporation, both the individual and the entity or corporation are agents. When a closed
To determine whether you or your agent made a campaign
contribution of more than $500 to a Pioneer Board member or other Pioneer official within the preceding 12 months, you must aggregate all such contributions.

Names of current Pioneer Board members and other Pioneer officials are available on Pioneer’s website.If you have questions about GovernmentCode Section 84308, FPPCregulations, or theCampaignDisclosure Form, please contactthe Pioneer Clerk.

CAMPAIGN CONTRIBUTION DISCLOSURE FORM
(a) Document:
□ License
□ Lease
□ Permit
□ Franchise
□ Other Contract
□ Other Entitlement
Name and address of any party, participant, or agent, who has contributed more than $500 to any Pioneer Board
Member or other Pioneer official within the preceding 12 months:

1. ____________________________________

2. ____________________________________

3. ____________________________________
(b) Date and amount of contribution:

Date Amount $
Date Amount $
(c) Name of Pioneer Board member or other Pioneer
official to whom contribution was made:

1. ____________________________________

2. ____________________________________

3. ____________________________________
(d) □ Check here If no contributions have been made to
any Board member or other Pioneer official in the
preceding 12 months.
(e) I certify that the above information is provided to the best of my knowledge.

Printed Name
Signature

369617.3
corporation is a party to a proceeding, the majority
shareholder is subject to these provisions. Date Phone
410921.1 Page 1 of 1
Staff Report – Item 6
To: The Governing Board
From: Eric Ponce, Information Technology Analyst
Item 6: Adopt a Resolution Approving Artificial Intelligence (AI) Acceptable Use Policy Date: 9/18/2025

RECOMMENDATION
Adopt a resolution approving Artificial Intelligence (AI) Acceptable Use Policy.

BACKGROUND / ANALYSIS & DISCUSSION
Pioneer Community Energy (Pioneer) recognizes the growing role of Artificial Intelligence (AI) in enhancing workplace efficiency, creativity, and innovation. AI tools such as large language models, automation systems, and chatbots offer significant opportunities to streamline workflows, support data analysis, generate content, and automate repetitive tasks.

The integration of AI into day-to-day operations also introduces new challenges, particularly in safeguarding sensitive information, maintaining data accuracy, and ensuring compliance with cybersecurity best practices.

Without clear usage standards, there is a heightened risk of unintentionally disclosing confidential or personally identifiable information through cloud-based AI tools or relying on AI-generated content without proper human oversight.

To ensure that AI is used responsibly and effectively across the organization, Pioneer has developed an AI Acceptable Use policy. This policy establishes clear guidance for staff on the secure and appropriate use of AI tools, in alignment with Pioneer’s existing Information Systems Acceptable Use policy and broader cybersecurity practices. By adopting this policy, Pioneer aims to empower staff to leverage AI for productivity and innovation while protecting organization data, maintaining public trust, and minimizing operational risk.

STRATEGIC PLAN
This development of the Artificial Intelligence (AI) Acceptable Use policy supports the Strategic Goal of Achieving Operational Optimization.

FISCAL IMPACT
The approval and implementation of the Artificial Intelligence (AI) Acceptable Use policy does not have a fiscal impact.

ATTACHMENTS
1) Resolution Establishing Artificial Intelligence (AI) Acceptable Use Policy Plf)NEER

COMMUNITY ENERGY
Before the Governing Board of
Pioneer Community Energy
Resolution No.: ____________
The following Resolution was duly passed by the Governing Board of Pioneer Community Energy at a regular meeting held September 18, 2025, by the following vote on roll call:

Ayes:

Noes:

Absent:

Signed and approved by me after its passage.
______________________________
Chair of the Governing Board
Attest:
_______________________
Secretary
WHEREAS, Pioneer Community Energy (“Pioneer”) increasingly relies on Information Technology (IT) systems to support daily operations and strategic initiatives, including customer service, data management, and external communications.

WHEREAS, Pioneer recognizes the growing role of Artificial Intelligence (AI) in enhancing workplace efficiency, creativity, and innovation.

WHEREAS, the integration of AI into day-to-day operations introduces new challenges, particularly in safeguarding sensitive information, maintaining data accuracy, and ensuring compliance with cybersecurity best practices.

WHEREAS, IT staff identified the need to develop an AI Acceptable Use policy to provide staff with guidance on the secure and appropriate use of AI tools, while encouraging productivity and innovation.

WHEREAS, Pioneer desires to adopt the Artificial Intelligence (AI) Acceptable Use Policy as part of its ongoing commitment to operational optimization, cybersecurity resilience, and best practices.

In the matter of: A RESOLUTION APPROVING

ARTIFICIAL INTELLIGENCE (AI) ACCEPTABLE

USE POLICY
Resolution 2025- ___
September 18, 2025
2 BE IT RESOLVED, the Governing Board of Pioneer Community Energy, State of California, hereby finds, declares, and resolves as follows:

1. The above recitals are true and correct.

2. The Governing Board hereby approves the adoption of the Artificial Intelligence (AI) Acceptable Use Policy “Exhibit A” in response to the growing role of AI in supporting workplace efficiency.

3. This Resolution shall take effect immediately upon its adoption.

Exhibit A: IT8 - Artificial Intelligence (AI) Acceptable Use Policy IT8
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410940.2

ARTIFICIAL INTELLIGENCE (AI)

ACCEPTABLE USE POLICY
I. PURPOSE
The purpose of this policy is to establish clear guidelines for the secure use of Artificial Intelligence (AI) tools at Pioneer Community Energy. While Pioneer encourages the use of AI to enhance productivity, creativity, and innovation, staff are expected to respect privacy, protect confidential information, and follow organizational cybersecurity standards.

II. BACKGROUND
AI tools, including large language models (LLMs), code assistants, automation tools and chatbots, offer powerful capabilities to enhance work processes. These tools can support research, content generation, customer service, and operational efficiencies.

However, they also introduce risks related to data privacy, accuracy, and unauthorized disclosure of sensitive information.

This policy provides staff with guidance for the safe and secure use of existing and future AI tools, especially where sensitive company or customer information is involved. All use of AI tools must align with Pioneer’s Information Systems Acceptable Use Policy and broader cybersecurity practices.

III. SCOPE
This policy applies to all Pioneer Staff that have access to the organization’s Information Resources.

IV. POLICY
Pioneer staff may use Artificial Intelligence (AI) tools in support of business productivity, innovation, and operational efficiency, under the following conditions:

IT8
Category: Information Technology
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410940.2
A. Permitted Use
All outputs produced by AI tools must be reviewed and validated for accuracy, tone, bias, and context by Pioneer staff before distribution or use in official business decisions. AI tools may produce erroneous or nonsensical information or results that are not real, do not match any data the algorithm has been trained on, or follow no other discernible pattern. In addition, the results may reflect biased or incomplete data sets on which the AI tool was trained. AI tools must not be used blindly for decision making and/or the creation of content and must never be solely relied upon for important inquiries.

Staff must label all text-based content and audio and visual media they created using AI as having been generated using AI regardless of modifications. Labels must be clearly visible to members of the public reviewing the content.

Example label:
“This document may have been drafted with support from AI-based tools, consistent with Pioneer’s policy on the use of artificial intelligence. All information represented in this document has been reviewed by Pioneer staff.”
Informal correspondence between Pioneer staff, such as emails, does not need to be labeled as having been created using AI.

Pioneer staff may only use Pioneer email addresses, phone numbers, or other Pioneer credentials, and not personal credentials, to create an account with AI services for use in their Pioneer work.

Pioneer staff may use AI tools to support business functions that include:
• Drafting content such as reports, presentations, and emails • Summarizing large public datasets or public documents • Assisting in generating code, formulas, or templates
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410940.2
• Automating repetitive tasks
• Translating text or improving grammar, tone, or clarity B. Restricted and Prohibited Use
Any information provided to a public AI tool is equivalent to making that information broadly available to the public.

The following activities are strictly prohibited:
• Submitting personally identifiable information (PII) or confidential data, including customer and employee data, into AI tools, particularly cloud-based or public platforms that can retain data.
• Uploading internal Pioneer documents, proprietary
business data, or system credentials into AI platforms, unless the tool has been formally approved by IT Support. • Using AI to fabricate data, impersonate individuals, or misrepresent facts.
• Relying on AI tools as the sole basis for regulatory
compliance, public communications, legal determinations, or final decision making.
• Using AI tools to generate offensive/discriminatory
content.
• Using AI tools to discriminate against an applicant or employee based on a characteristic protected by state or federal law, for the purposes of hiring or making other personnel decisions. AI tools may be used for the purposes of hiring or making other personnel decisions only upon anti-bias testing of the AI tool, or other similar proactive efforts to avoid unlawful discrimination.
• A “deepfake” is an image, video, or audio record that has been digitally altered to replace one person’s likeness with another person, or a computer-generated image or video
of a person doing or saying something the person was not actually recorded or photographed as having done or said.

Creation of “deepfake” images, video, or audio for Pioneer work or on Pioneer resources or equipment is strictly
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410940.2
prohibited. Use of “deepfake” images, video, or audio for Pioneer work or on Pioneer resources or equipment, other than using it as evidence in or as part of an administrative investigation, is strictly prohibited.

C. Security and Approval
• AI services that access or process Pioneer data must be evaluated and approved by IT Support prior to use.
• Staff must not bypass security protocols, store sensitive data in unapproved AI applications, or disable protections (e.g., firewalls, malware detection).
• If Pioneer staff become aware of an instance where an AI system has caused harm or poses a risk of causing harm, such as compromising data security, violating privacy,
producing discriminatory or biased outcomes, or otherwise disrupting business operations, they must promptly report the issue to their supervisor and IT Support.
• All staff AI searches must be in “incognito” mode or “opt out” or other similar mode to prevent the AI tool from
retaining or using the information provided for the tool or service’s use in any manner, including to train or improve the AI tool or service, or to share the information with any third party.

D. Monitoring and Oversight
• All AI activity using Pioneer Information Resources may be subject to audit or monitoring to ensure compliance with this policy.
• Pioneer reserves the right to suspend or revoke AI access privileges in cases of suspected misuse or risk.
• IT Support may be granted broader access to AI tools to support infrastructure, security, or system administration tasks, and are subject to oversight by the Director of
Finance and Administration.

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410940.2
V. DISTRIBUTION
Any staff member found to have violated this policy may be subject to disciplinary action, up to and including termination.

VI. DISTRIBUTION
This policy is to be distributed to all Pioneer staff who use Information Resources.

VII. Policy Revisions
The Chief Executive Officer is authorized to make minor modifications, clarifications, or administrative updates to this policy, provided that such changes do not alter the policy’s intent, scope, or underlying principles.

VIII. HISTORY
Version Date Description Approved By
2025.1 9/18/25 Initial policy release

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 9/18/2025

PERSONNEL
The recruitment of the Legislative Analyst position has closed with an offer accepted and an expected start date in October. This position will focus on moving reliability related projects such as microgrids through the regulatory process. We look forward to introducing our newest employee at the October Board meeting.

There are two active recruitments for a Power Supply Manager/Analyst position and Customer Care Coordinator.

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) The following agreements have been carried out by the Chief Executive Officer, consistent with the authority delegated by the Board:
 Consultant Services Agreement with PFM Financial Advisors for 2025 services in an amount not to exceed $25,000.

MICROGRID INCENTIVE PROGRAM (“MIP”) UPDATE
On July 25, Pioneer issued an Request for Proposal (“RFP”) to interested engineering firms for services related to completing the Pacific Gas & Electric (“PG&E”) technical applications under the Microgrid Incentive Program for four potential microgrid projects sites; two located in Grass Valley, another in Foresthill and the fourth located in Georgetown. Several interested firms reached out to Pioneer and ultimately three submitted RFP proposals-Wisewood & PAE, Arup, and Mavericks Renewables. After consideration, Pioneer staff awarded the RFP to Arup for both Grass Valley sites and Wisewood & PAE for the Foresthill and Georgetown sites. Staff is in the process of finalizing the consultant services agreement with the awarded firms. Thereafter, staff will move into the formal consultation phase with PG&E to identify and develop the specific microgrid boundaries. This process will be completed by mid-October, and the technical partners will then begin the official technical design and engineering phase. The subsequent two months will entail Pioneer working with the technical partners to provide relevant data and direction, and community outreach and updates as necessary based on the project design process. The technical applications are due in mid-December with award announcements to follow in Q1 2026.

UPCOMING GEYSERS TOUR
Just a reminder that Pioneer is hosting a tour of the Calpine Geysers on Friday, November 7, from 10:00 – 3:00.

Located north of San Francisco in the Mayacamas Mountains, the Geysers are the nation’s largest renewable geothermal power producer. This will be a fascinating tour and a very informative day, as we will have a chance to see how a geothermal power plant operates. Please RSVP to Gina or Teresa if you would like to attend or want additional information.

Plf)NEER

COMMUNITY ENERGY
Agenda Item: IV-B Agenda Date: 9/18/2025

SUPPLIER DIVERSITY PERFORMANCE
The California Public Utilities Commission (“CPUC”) through General Order 156 is a program promoting and monitoring utilities’ procurement from diverse businesses like women-owned, minority-owned, disabled veteran-owned, and LGBT-owned enterprises.

I am proud to report Pioneer ranked #1 amongst Community Choice Aggregators (“CCA”) for diverse spending in 2024 for goods and services (non-power supply).

JOINT RATE MAILER (“JRM”)
A JRM is an annual notice sent by a CCA, such as Pioneer Community Energy, to its customers. This mailer, required by CPUC, compares the cost of electricity generation between the CCA and the utility (e.g., PG&E). • It is intended to show customers the financial benefits, such as average cost savings, of being with the CCA.
• The mailer also includes a comparison of typical electricity rates and the sources of energy used (the generation portfolio).

Staff completed the distribution of the JRM to all our ratepayers before the September 1st deadline. PG&E only allowed two Power Charge Indifference Amount (“PCIA”) vintages to be used for the JRM so the 2017 (i.e.

Placer) and 2021 (i.e. El Dorado) PCIA vintages were applied due to the most customers enrolled in those vintages. Please see attachment 5a-5d for a listing of both residential and commercial rates.

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

Presentations and Relevant Meetings attended by the Chief Executive Officer

1. Participated in CalCCA Weekly/Monthly Board meetings.

2. Pioneer sponsored and presented at League of Cities event in Yuba City

3. Participated in annual RCRC Conference

4. Participated in a meeting with PCWA to discover opportunities to collaborate

5. Participated and a sponsor of Rural Counties Representatives of California annual conference.

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report

5. Joint Rate Mailers
a. Residential – Placer
b. Residential – El Dorado
c. Commercial – Placer
d. Commercial – El Dorado
Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
Janus Solar PV, LLC 9/2/2025 Buy Renewables - PCC1 6/1/2027 5/31/2042 $193,085,987 Janus Solar PV, LLC 9/2/2025 Buy Resource Adequacy - Flex 6/1/2027 5/31/2042 $239,040,000 Calpine Energy Services, L.P. 7/9/2025 Sell Resource Adequacy - Flex 11/1/2025 11/30/2025 $100,000 Chalan CA Solar Storage, LLC 6/30/2025 Buy Renewables - PCC! 12/1/2026 11/30/2046 $196,117,073 Chalan CA Solar Storage, LLC 6/30/2025 Buy Resource Adequacy - Flex 12/1/2026 11/30/2046 $88,560,000 Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 09-11-25

BOARD OF

DIRECTORS
SEPTEMBER 18, 2025
2:15 PM – SPECIAL MEETING
3:00 PM – REGULAR MEETING
(Post Agenda: September 12)
OCTOBER 16, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: October 10)
NOVEMBER 20, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: November 14)

IN THE FUTURE
Special Meeting
Closed Session 2:15 PM
(1)Conference with Labor Negotiators
(2)Conference with Legal Counsel
Regular Meeting
Consent 1a Minutes for Approval-JULY 10, 2025 Minutes for Approval-SEPT 18, 2025 Minutes for Approval-OCT 16, 2025 DEC RES IT Policies – part 3 (Koehn) 1b RES Power Source Disclosure Report &
Attestation (Kang)
Receive Draft Financials JUN-JUL 2025
(Koehn)
Receive Draft Financials AUG 2025
(Koehn)
2026 RES Yes Energy (Kang)
1c (cost-neutral programs) Launching
Clean Fleet Revenue Program to New
Members (Stassi-Vanacore)
RES Compensation Adjustments;
Employee Welfare & Benefits (Koehn)
RES IT Policies – part 2 (Koehn) RES Facilities Lease (Koehn) 1d RES LMS Compliance Plan (Kang) RES IT Policies – part 1 (Koehn) 1e RES BB&W Contract (Koehn)
Presentation 2 Power Charge Indifference Adjustment
(discussion-Eckert)
guest: Brian Dickman (in person)
Presentation (discussion-Eckert)
guest: Dr. Ahmad Faruqui (in person)
Calpine Grant Award Presentation –
(action- Stassi-Vanacore)
DEC RES JPA Amendment No. 8
(action-Eckert)
Regular 3 RES Expansion Update
(action-Stassi-Vanacore)
RES Rebate Program
(action-Stassi-Vanacore)
RES IRP (Integrated Resource Plan) –
(action-Kang)
DEC RES Addendum No. 4 to
Implementation Plan (action-Eckert)
4 RES Revised NEM Policy (action-Koehn) Approve 30-Day Notice for DEC 18 vote (JPA Amendment No. 8) (action-Eckert)
MIP Update
(discussion-Stassi-Vanacore)
DEC Programs Year-in-Review
(discussion- Stassi-Vanacore)
5 RES Incentive Finder Program
(action-Stassi-Vanacore)
Update on advertising campaign
(discussion- Stassi-Vanacore)
PCIA Updates (discussion-Kang) DEC PH – RES Rates (action-Eckert) 6 RES AI Acceptable Use Policy
(action-Koehn)
Fiscal Year 2024-25 in Review
(discussion-Koehn)
End of Legislative Session Update
(discussion-Kang)
DEC Power Procurement Year-in-Review
(discussion-Kang)
DEC-JAN Annual Audit (discussion)
DEC-JAN 2026 Governing Board Schedule
JAN Annual Selection of Board Officers
(action-Eckert)
JAN Annual Appointment of EPRC
Members (2026)
General Function II Chief Executive Officer’s Report
REG Reports:

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

Leg/Reg; Communications; Programs;
QTRLY Updates requested by the Board
 Strategic Plan Objectives  Sponsorship Activity
Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Chief Executive Officer’s Report
QTRLY Updates requested by the Board
JAN – APR – JULY – OCT
 Strategic Plan Objectives
 Sponsorship Activity
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms
Informational Items
Glossary of Terms FEB Celebratory Toast-Debt Free
7 LJ
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 09-11-25

AUDIT/FINANCE COMMITTEE TO BE SCHEDULED IN THE FUTURE
David Ring, Chair
Richard Pearl, Vice Chair
Greg Janda
Gary Petersen
o May 12, 2025 Minutes
o Rates
o Financial Audit

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE
MONDAY, OCTOBER 6, 2025
4:00 PM
zoom only

IN THE FUTURE
Gary Petersen, Chair
Alice Dowdin Calvillo, Vice Chair
Ryan Carter
Greg Janda
Sean Lomen
o PPA – Shell (JAN-BOARD) Annual Appointment of EPRC Members (2026)

EXPANSION

AD HOC COMMITTEE
TUESDAY, OCTOBER 14, 2025
10:00 AM
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy, Vice Chair
Suzanne Jones
Lori Parlin
o Review Impact Assessment Study results
GOVERNANCE COMMITTEE THURSDAY, SEPTEMBER 11, 2025
3:00 PM
in-person & remote locations

IN THE FUTURE
Board - Chair
Board - Vice Chair
Committee Chairs
Board Chair, Ex Officio (prior year)
o Closed Session (Compensation Study; Welfare & Benefits) o Open Session:
public report of Closed Session
April 15, 2025 Minutes
o Administration of Meetings for Large Boards

COMMUNITY ADVISORY COMMITTEE
TO THE CHIEF EXECUTIVE OFFICER OCTOBER 22, 2025 IN THE FUTURE Meets on the 4th Wednesday
(even-numbered months)
December (date TBD)
I

Attachment: Legislative and Regulatory Update
Date: 9/18/2025

Legislative Affairs
• As part of Pioneer’s 2025 Legislative Policy and Platform that the Board of Directors approved, Pioneer staff have submitted letters of support for the following bills:
o AB 706 (Aguiar-Curry): This is a Pioneer sponsored bill that would establish the FOREST and Wildfire Prevention Fund, to promote biomass utilization that contributes to California’s wildfire fuel reduction targets while providing clean firm energy to improve grid resiliency. o AB 66 (Tangipa): This bill would provide a temporary CEQA exemption, until January 1, 2032, for projects that create or improve emergency egress routes in residential areas and communities that currently lack a secondary route.
o SB 88 (Caballero): This bill would require the California Air Resources Board, CalFire and the California Energy Commission to take specific steps to track, locate, and quantify the emissions from the burning of forest and agricultural waste. This bill intends to monetize the value of avoided emissions during biomass waste utilization processes and encourage the beneficial use of biomass residues to prevent wildfires and avoid managed open pile burning. o SB 540 (Becker): This bill would provide the California Independent System Operation (CAISO) with authority to implement the “Pathways Initiative”, which would allow CAISO to tap into a wider market of electricity sources throughout the broader Western region. Many studies have shown establishing a regional energy market stands to provide Californians with significant cost savings, enhanced grid reliability, and reduced air pollution. o AB 1227 (Essayli): This bill would affirm the Governor’s State of Emergency Proclamation, issued on March 1, 2025, ordering state agencies to fast-track critical wildfire prevention projects, by requiring specified state agencies to report on these expedited projects. The bill would also create a temporary CEQA exemption, until January 1, 2028, for critical fuels reduction projects conducted in communities located in high fire hazard severity zones. • Pioneer-sponsored bill, AB 706 (Aguiar-Curry) has been put on pause by the author’s office, due to the delay in budget negotiations. The author’s office is still committed to advocating for funding allocation for a biomass development program, as outlined in AB 706, through the ongoing budget negotiations. • On SB 540 (Becker), Pioneer changed its position from “Support” to “Oppose unless amended (OUA)” due to concerning provisions that were added through Senate amendments. Our specific areas of concern are the creation of the Regional Energy Markets Oversight Council, the inclusion of legislative oversight with the appropriate committees, revisions to the Renewable Portfolio Standard, and unnecessary restrictions on future markets. These added provisions create significant roadblocks to achieving the bill’s original intent of enabling the creation of a robust regional Western energy market.

Pioneer sent updated letters expressing our OUA position to our constituent legislators and signed onto two coalition letters, along with a number of other CCAs and CalCCA, urging the Legislature to pass a workable version of SB 540.
• As of August 29, 2025, the deadline for bills to be passed out of their respective fiscal committees, below are the results for Pioneer’s remaining high priority bills:
o AB 66 (Tangipa): Failed to pass by the deadline, held in Senate policy committee o SB 88 (Caballero): Passed by Assembly appropriations with amendments o AB 1227 (Essayli): Failed to pass by deadline, held in Senate appropriations Plf)NEER

COMMUNITY ENERGY
[Publish Date] Agenda Date: 9/18/2025

Regulatory Proceedings
Below is a summary table of the key terms and issues, followed by further details on activities since our last Board Meeting on a few ongoing priority Pioneer regulatory proceedings and matters. More updates will follow at future Board meetings as regulatory proceedings and matters evolve.

Key Terms
CPUC- California Public Utilities Commission CAISO- California Independent System Operator CEC- California Energy Commission OIR- Order Instituting Rulemaking/ “Proceeding” LSE- Load Serving Entity AL- Advice Letter
IOU- Investor-Owned Utility PD- Proposed Decision
ALJ- Administrative Law Judge
Proceeding Issue Pioneer Position
R.22-10-010 OIR to Implement AB 843 (2022) –
The Bioenergy Adjusting Tariff
Program (BioMAT)
Expeditiously implement AB 843 to
allow CCA access to the BioMAT
program for future subsidies for
biomass procurement
R.20-05-003 OIR to Continue Electric Integrated
Resource Planning (IRP) and
Related Procurement Processes
Advocate for procurement planning
policies that prioritize affordable
baseload resources such as biomass
energy
R.24-01-017; CEC OIR 21-RPS-02
OIR to Continue Implementation
and Administration, and Consider
Further Development, of California
Renewables Portfolio Standard
Program (RPS)
Ensure Pioneer maintains
compliance with RPS mandates and
advocate for fair inclusion of
biomass in RPS guidelines
R.23-10-011 OIR to Oversee the Resource
Adequacy (RA) Program, Consider
Program Reforms and Refinements,
and Establish Forward Resource
Adequacy Procurement Obligations
Refine the current RA Program
construct; reduce volatility of RA
prices; increase RA procurement
availability and grid reliability
R.22-07-005 OIR to Advance Demand Flexibility
Through Electric Rates
Limit negative impacts of the
Income Based Graduated Fixed
Charge and educate Pioneer Board
and customers prior to the rollout.

A.20-02-009; A.21-03-008;
A.21-06-001; A.22-05-029;
A.24-05-009; A.25-05-011
PG&E 2019 Energy Resource
Recovery Account (ERRA)
Compliance Application; PG&E 2020
ERRA Compliance Application; 2021
ERRA Compliance Application; 2022
ERRA Compliance Application; 2023
ERRA Compliance Application; 2023
ERRA Forecast Application; 2024
ERRA Forecast Application; 2024
ERRA Compliance Application; 2025
ERRA Forecast Application; 2026
ERRA Forecast Application
Reduce the ERRA impact on the
PCIA; increase data transparency
from the IOUs
R.21-03-011 OIR to Implement Provider of Last
Resort (POLR)
Limit the impacts of changes to the
Financial Security Requirement
(FSR)
[Publish Date] Agenda Date: 9/18/2025

R.18-12-005 Utility De-energization, Public
Safety Power Shutoffs (PSPS), and
Enhanced Powerline Safety Settings
(EPSS)
Reduce impacts of PSPS and EPSS
events; increase coordination and
communications with IOUs to
ensure public safety during de-energization; limit PSPS and EPSS impacts on CCA load scheduling
CEC 21-OIR-03; 23-LMS-01 Load Management Standards (LMS) Ensure Pioneer maintains compliance with CEC mandates and
requirements
R.25-02-005 OIR to Update and Reform Energy
Resource Recovery Account (ERRA)
and Power Charge Indifference
Adjustment (PCIA) Policies and
Processes
Advocate for ERRA and PCIA
reforms that will not result in unfair
cost shifts between bundled and
unbundled customers
AB 843 BioMAT Implementation:
• October 20, 2022- The OIR was opened to examine the implementation of AB 843. • November 30, 2023- The CPUC voted to approve the revised PD which clarified many of the issues raised in the comments of the PD, while retaining the favorable outcome for CCAs. • January 2, 2024- The IOUs submitted their Tier 2 ALs modifying the BioMAT Tariff to incorporate CCAs. • January 29, 2024- 60 days from the Decision- CCAs finalized two provisions with Accion for website work and third-party administrator. In addition, CCAs submitted a revised tariff, a program participation request, power purchase agreement, rate schedule, and balancing statement as part of a Tier II AL to the CPUC. • February 1, 2024- Tier III ALs were submitted by 4 CCAs indicating interest in participating in the BioMAT program (3CE, Pioneer, RCEA, and OCPA).
• February 23, 2024- CalCCA submitted a 15-day extension until March 14 to meet the requirement for the central BioMAT Accion webpage and standard framework for individual CCA webpages within 90 days of the decision due to an issue raised by Accion in the third-party administrator Statement of Work that the CCAs, IOUs, and Accion are attempting to resolve.
• February 25, 2024- RCRC submitted reply comments in support of the Joint CCAs proposal to consider extending the BioMAT program sunset date.
• March 1, 2024- A group of CCAs (Pioneer, RCEA, 3CE, OCPA, MCE, and VCE) submitted comments in the RPS proceeding asking the CPUC to consider expediting consideration of an extension to the BioMAT program beyond 2025.
• March 5, 2024- There is an agreement with Accion as the Third-Party Administrator. The agreement has been reviewed and signed by Pioneer as well as the other 3 CCAs. • March 21, 2024- There was a meeting with CPUC staff on implementation of AB 843. Brad Hill will be moving over to the Natural Resources Agency.
• March 28, 2024- Assembly Member Aguiar-Curry submitted a letter of support to the CPUC for the extension of the BioMAT program. This letter included the support of other legislators: Senator Alvarado-Gil, Senator Dahle, Senator Talamantes Eggman, and Assembly Member Dahle. • March 28, 2024- CalCCA submitted a third request for extension of time for an additional 31-day extension of time (until April 29) for the central BioMAT Accion webpage and standard framework for individual CCA webpages to be completed within 90 days of the effective date of the decision. Work has been delayed pending final agreement from all parties to revisions to the third-party administrator Statement of Work. • April 4, 2024- There was a prehearing conference to address the preliminary scope of issues in the OIR for IRP where the Joint CCAs are asking for an extension of the BioMAT program. During this conference, Scott Blaising represented the Joint CCAs and asked for 1) the CPUC to expedite the extension of the BioMAT program and 2) broadly review the program.
• May 1, 2024- CPUC approved the joint CCAs Tier 2 Advice Letter which approved the BioMAT standard [Publish Date] Agenda Date: 9/18/2025

program documentation which included the tariff, the pro-forma power purchase agreement, program participation request forms, BioMAT program website and portal development contracts, independent third-party contracts, initial balancing account statements, and non-bypassable charge rate scheduled. • Pioneer has completed the implementation of the BioMAT program. The website and all necessary documents for BioMAT are live.
• June 20, 2024- CPUC issued a Draft Resolution to approve participating CCAs’ forecast revenue requirements, which is $0 for 2024-2025 for all participating CCAs, since no BioMAT projects are forecasted to COD before then.
• September 1, 2024- CPUC granted the joint CCAs’ extension request for the BioMAT application for prudent contract management, since there are no BioMAT contracts to report on. The new deadline will be 6 months after the first BioMAT contract is executed or September 1, 2025, whichever date comes first. • January 31, 2025- Pioneer submitted a Tier 3 AL to seek cost recovery for forecasted revenue requirements for 2026, which are $0.
• March 6, 2025- The CPUC issued a notice to Pioneer, informing us that our Tier 3 AL seeking cost recovery for BioMAT forecasted revenue requirements for 2026 is suspended for review for up to 120 days beginning March 3, 2025.
• April 7, 2025- Pioneer filed supportive reply comments to the Bioenergy Association of California (BAC)’s Petition to Modify (PFM) CPUC Decision 20-08-043 in the 2018 RPS proceeding, regarding changes to the BioMAT program. In its PFM, BAC urged the CPUC to extend or remove the sunset date on the BioMAT program, along with other program revisions, to ensure the program can meet its statutory requirement of enabling the procurement of 250 MW of distributed generation bioenergy. Pioneer, in partnership with the Redwood Coast Energy Authority (RCEA), filed comments, detailing our BioMAT project development efforts and urging the CPUC to consider expedited action on the extension of the BioMAT program, considering it is scheduled to sunset at the end of 2025. Pioneer’s comments also echoed BAC’s other requested changes to the BioMAT program to enable more subscription, including improving interconnection issues and removing cost caps for Category 3 projects using forest biomass waste. • In the weeks of August 25th and September 1st of 2025, Pioneer and RCEA conducted five ex-parte meetings with the offices of commissioners assigned to the RPS proceedings where the issue of BioMAT implementation is being considered. The purpose of the ex partes was to request for the Commission to expeditiously grant a five-year extension of the BioMAT program, considering the sunset date of December 31, 2025 is quickly approaching. In the ex-partes, Pioneer and RCEA presented on the background of CCAs’ interest and involvement in BioMAT, our current efforts to implement the program, and justifications for why BioMAT should be extended. The commissioners’ offices did not explicitly address if or when the issue of BioMAT extension will be considered in the current RPS proceeding.

Integrated Resource Planning:
• October 7, 2015- The California Legislature adopted SB 350, the Clean Energy and Pollution Reduction Act of 2015, which increased the state’s greenhouse gas reduction target, requiring 50% renewable electricity procurement by 2030, and mandating a doubling of energy efficiency. To meet these goals, SB 350 ordered large utilities to develop and submit integrated resource plans (IRPs), which will be reviewed by the CPUC.

The IRP proceeding serves as the vehicle for the CPUC to evaluate utilities’ progress towards meeting the SB 350 goals, as well as the general planning proceeding to consider California’s long-term energy needs and electric procurement policies.
• June 24, 2021- In Decision 21-06-035, the CPUC ordered the collective procurement of 11,500 MW of new net qualify capacity (NQC) to come online in 2023-2026. 2,000 MW NQC must come from long lead-time resources providing clean firm power or long duration energy storage. • March 13, 2023- In Decision 23-02-040, the CPUC ordered the collective procurement of an additional new 4,000 MW NQC in 2026-2027. The decision also extends the deadline for procurement of new long lead-time resources to 2028.
• October 7, 2024- Pioneer filed reply comments in response to the ALJ’s ruling seeking comments on the proposed resource portfolios for the 2025-2026 Transmission Planning Process (TPP). Pioneer urged the [Publish Date] Agenda Date: 9/18/2025

Commission to recognize the value of biomass as a clean firm resource needed to meet reliability and renewable energy goals. Our comments ultimately recommended an increase of 0.1 GW growth of biomass in the proposed portfolio.
• January 10, 2025- The CPUC issued the PD transmitting electricity resource portfolios to the CAISO for the 2025-2026 TPP. The PD failed to adopt many of the requests made by party comments, including Pioneer’s recommendation to increase the growth of biomass.
• January 10, 2025- The Long Duration Energy Storage (LDES) Council filed a petition for modification (PFM), urging the CPUC to clarify that derated short-duration battery energy storage cannot be used to meet the mid-term reliability procurement obligation for long-duration storage, as ordered in Decision 21-06-035.

Pioneer does not have any derated short-duration battery energy storage resources in our portfolio that would be negatively impacted if the PFM were to go into effect. • February 10, 2025- CalCCA responded to the LDES Council’s PFM, recommending the CPUC to deny the petition due to the clear nature of the language already present in the original decision, as well as to avoid the precedent of retroactive policymaking which would disadvantage LSEs who already made procurement decisions based on the given language.
• February 20, 2025- The CPUC issued the final decision (D. 25-02-026) transmitting electricity resource portfolios to the CAISO for the 2025-2026 TPP, which adopted the originally proposed base case and sensitivity portfolios.
• April 29, 2025: The CPUC issued a Staff Proposal on the Reliable and Clean Power Procurement Program (RCPPP), with an ALJ ruling seeking comments. RCPPP is a new proposal for a long-term procurement planning framework, intended to forecast procurement needs for reliability and GHG reduction goals 10 years forward. Pioneer staff will review and work with CalCCA to provide comments. • May 15, 2025- CalCCA requested a deadline extension on comments to the RCPPP Staff Proposal and was granted an extension from the original deadline of June 5 to July 15. In the meantime, CPUC Staff will host two workshops to facilitate stakeholder discussion on the RCPPP proposals, which include two options for a reliability procurement framework and one option for a new GHG reduction procurement framework called the “Clean Energy Standard (CES)”. In these discussions, Pioneer will continue to advocate for programmatic changes and policies that allow us to meet state-mandated reliable clean energy goals, while limiting unnecessarily complex and costly compliance measures. • July 15, 2025- CalCCA filed opening comments on the RCPPP Staff Proposal, supporting the development of a long-term procurement framework that takes into account the practical realities and constraints LSEs face in the current procurement environment (supply chain issues, interconnection delays, federal policy changes). CalCCA supported the adoption of an RCPPP reliability framework beginning in 2029 resembling Staff Proposal’s Option I with modifications to 1) align RCPPP to the RA program using the SOD methodology, 2) establish 5-year forward showing requirements in alignment with RA processes, 3) remove the proposed buffers in favor of LSE-level risk management, 4) adopt a penalty waiver process, 5) clearly define the “good faith efforts” standards adopted in the MTR order, and 6) incorporate sufficient transactability mechanisms to prevent over-procurement. CalCCA also supported development and adoption of the CES GHG-emissions reduction framework based on actual energy sales as an extension of the RPS program beginning in 2031. CalCCA urged the CPUC to coordinate with the CEC to develop a workshop process aimed at ensuring load forecast accuracy at the hourly level by LSE. CalCCA’s reply comments further urged the CPUC to consider the constraints in the current procurement environment by rejecting party recommendations for near-term procurement orders without rigorous needs assessment, overly prescription RCPPP frameworks that would establish long lead time (LLT) specific requirements, enforced procurement of the preferred system portfolio (PSP), and establishing excessively high procurement requirements in forward years.
• July 21, 2025- American Clean Power- California (ACP-CA) filed a motion to amend the current IRP scoping memo to include an additional track for expedited procurement of clean resources eligible for the expiring federal tax credits (investment tax credit/ production tax credit (ITC/ PTC)). ACP-CA’s motion suggests for this procurement to be done by IOUs, with costs allocated to all LSEs through the cost allocation mechanism (CAM). Pioneer filed a response highlighting the breach in procurement autonomy afforded to CCAs under law that the ACP-CA motion represents. Pioneer also supported CalCCA’s response which asserts the ACP-CA [Publish Date] Agenda Date: 9/18/2025

motion should be rejected on the basis that it does not meet the robust needs assessment required for procurement orders, cannot substantiate its claims of customer savings, and would only serve to further constrain the procurement environment. ACP-CA replied to CalCCA’s response, claiming that “CCAs are waiting on the sidelines” and not actively seeking procurement of ITC/ PTC eligible resources, to which CalCCA filed a sur-reply requesting the CPUC dismiss ACP-CA’s reply due to its mischaracterization of CCA procurement activity, as shown through CCA solicitation data. • August 1, 2025- CalCCA filed opening comments on the new IRP OIR, R.25-06-019, which includes recommendations to the scope and schedule of the new proceeding. CalCCA recommended that the individual LSE IRP plans should be due no earlier than February 2026 or six months after the IRP filing materials and compliance guidelines are issued.
• August 13, 2025- The CPUC issued a PD in response to Southern California Edison’s (SCE) petition for modification (PFM), seeking a waiver for the bridge contracts requirement for MTR resources in non-peak months. SCE PFM’s argued that there is no short-term reliability need for bridge resources during non-peak months, and LSEs already demonstrate fulfillment of short-term reliability needs by meeting their month-ahead RA requirements. The CPUC’s PD recognizes that short-term reliability needs are already met through RA compliance, and that the MTR bridging requirement imposes unnecessary ratepayer costs. The PD goes beyond the relief requested by SCE by eliminating the option for LSEs to use bridge contracts as an alternative compliance mechanism for long lead time (LLT) resource requirements in the MTR orders for all months of the year. CalCCA filed opening comments, urging the CPUC to clarify the intent of the PD and reduce ambiguity by adopting SCE’s PFM with modifications to apply it to all months. CalCCA asked the CPUC to confirm that adoption of the PD would mean LSEs will not be found out of compliance with their MTR obligations if they have a contract that is either delayed or has been terminated for reasons beyond their control, if they are meeting their RA requirements and making good faith efforts to replace the contract. CalCCA also urges the CPUC to more clearly define the “good faith efforts” standard and consider the issue of alternative pathways to compliance for LLT resource delays in the current or new IRP proceeding.

Renewables Portfolio Standards:
• September 12, 2002- The Renewables Portfolio Standards (RPS) program was established in 2002, by Senate Bill (SB) 1078 with the initial requirement that 20% of electricity retail sales must be served by renewable resources by 2017. The program was accelerated in 2015 with SB 350 which mandated a 50% RPS target by 2030. In 2018, SB 100 was signed into law, which again increased the RPS target to 60% by 2030 and requires all the state’s electricity to come from carbon-free resources by 2045. The RPS proceeding at the CPUC serves as the vehicle for the CPUC to implement and administer RPS compliance rules for LSEs including Pioneer. Concurrently, the CEC is responsible for the certification of electrical generation facilities as eligible renewable energy resources and adopting regulations for the enforcement of RPS procurement requirements.
• July 22, 2024- Pioneer filed our Draft 2024 RPS Procurement Plan to the CPUC. • August 1, 2024- Pioneer submitted our 2023 RPS Compliance Reporting materials to the CPUC. • November 1, 2024- Pioneer filed comments on the CEC RPS docket, regarding the Draft 10th Edition of the RPS Eligibility Guidebook. Our comments urge the CEC to consider changes to the Guidebook that would reduce barriers to the certification of biomass facilities and burdens associated with reporting and verification. Furthermore, Pioneer recommended that the Guidebook should provide guidance to potential developers on eligible biomass conversion technologies and ensure accurate accounting of the generation from these sources.
• June 30, 2025- Pioneer filed our 2025 RPS Procurement Plan to the CPUC, providing an overview of our procurement progress and plans to meet current and future load needs for our service territories, in accordance with the RPS mandates.

Resource Adequacy:
• May 25, 2023- The CPUC issued a PD barring non-compliant LSEs from expansion for two calendar years following a system RA deficiency.
[Publish Date] Agenda Date: 9/18/2025

• June 14, 2023- CalCCA filed comments recommending the CPUC fully reject the PD’s restrictions on LSE expansion due to RA deficiencies and modify the RA deficiency penalty.

June 29, 2023- The CPUC issued a decision adopting a one percent minimum threshold for RA deficiencies that would limit CCA expansions; clarifying that if an LSE “cures” its year-ahead RA deficiency in the month-ahead timeframe, the year-ahead deficiency will not be applied to the expansion requirement. • July 26, 2023- CalCCA and CCCE filed two Applications for Rehearing (AfR) of the decision to limit CCA expansion for two years due to uncured RA deficiencies. CalCCA’s PfR cited a lack of CPUC statutory authority to limit CCA expansion, and that it gives itself new unauthorized powers to needlessly discriminate against CCAs to prevent their growth; it also asserted, that without credible evidence, the CPUC determined that addition of new CCA load would be detrimental to grid reliability, and that the decision violates the CPUC’s legal requirement to apply RA enforcement measures in a nondiscriminatory manner, not just to CCAs.
• On September 19, 2023, PG&E and SCE submitted their annual central procurement entity (CPE) reports.

PG&E is short RA for all months - up to 4,400 MW.
• October 12, 2023- The Commission opened the new RA proceeding through OIR R.23-10-011, which proposes the scope, schedule, and administration of this next RA proceeding. • November 9, 2023- CalCCA submitted comments recommending additional scoping items for the RA proceeding, including additional refinements to the RA program for the local RA CPE, compliance and penalty structure, slice-of-day (SOD) transactability, and RA import rules. • December 14, 2023- CPUC denied CalCCA’s request for a rehearing of the decision on RA procurement obligations and the prohibition against CCA expansion for failure to comply. • January 17, 2024- Petition for Writ of Review prohibition of CCA expansion filed. Shell also filed a petition for somewhat different reasons. CPUC is seeking to consolidate since there are two filings. CalCCA did not oppose the motion.
• January 19, 2024- Proposals due in the RA proceeding for Track 1, addressing time-sensitive issues that must be resolved for the 2025 RA compliance year. CalCCA has identified 3 major problems that the RA proposals should address: RA market scarcity, the potential exercise of market power, and removing the economic incentives not to comply. CalCCA is seeking to remove the prohibition from CCA expansion in the event of noncompliance and add the ability for the CPUC to waive penalties if CCAs can show reasonable efforts to comply were unsuccessful. The RA proposal approved by CalCCA’s Board included a temporary waiver proposal for system and flexible RA from 2025 to 2027. Partial waivers would waive the penalty points and non-fiscal consequences, and a full waiver would also be available that would waive financial penalties as well under certain circumstances. A slice of day waiver would also be available. • February 23, 2024- There was a SOD proposal workshop. CalCCA is asking for a delay in SOD implementation from 2025 until 2026 because the showing and compliance tools are not working properly. • March 22, 2024- CalCCA submitted comments on the RA Program with regards to considering RA reforms and refinements and establishing forward RA procurement obligations. CalCCA believes the focus should be to adopt proposals that protect customers against excessive RA costs and increase RA capacity availability. • June 6, 2024- CalCCA filed comments on the CPUC’s RA Track 1 PD, regarding key issues with SOD implementation. CalCCA emphasized how customer affordability will be put at risk due to the hourly transactability issue, and the CPUC’s refusal to delay SOD implementation or offer system RA waivers. The comments also included a host of other issues including the CPUC’s insistence on using a higher than necessary planning reserve margin (PRM), exclusion of existing resources in cure period extensions, restrictions on the amount of RA imports allowed, and concerns about the resource counting methodology. • June 14, 2024- CalCCA filed comments on the Assigned Commissioner’s Scoping Memo and Ruling on Track 2, proposing an adjustment of the CPE timeline. Currently, the Commission authorizes the CPE to procure local RA until 2 months before LSEs must submit their year-ahead RA showings. This leaves LSEs with limited time to fill their shortages in response to CPE allocation. CalCCA’s proposal urges the Commission to require the CPE to provide their LSEs with their local RA allocations at least 1 year prior to their year-ahead RA filings.
• June 20, 2024- The CPUC issued a decision to adopt local capacity requirements for 2025-2027, flexible [Publish Date] Agenda Date: 9/18/2025

capacity requirements for 2025, and refinements to the RA program as scoped in Track 1. The Commission maintains that the 2025 RA compliance year will be the first year for the new SOD framework, but remains open to considering hourly transactability after implementation, should any issues arise. • August 23, 2024- CalCCA filed reply comments on the ALJ ruling modifying the Track 2 schedule, expressing concerns about the upcoming loss of load expectation (LOLE) study and how it will be used to set the PRM for SOD implementation, and the proposed changes to the CPE framework and timeline. • August 30, 2024- Energy Division (ED) published the revised version of their RA LOLE study, which the CPUC will use to calibrate the PRM for the 2026 SOD implementation. Based on the LOLE study, ED staff recommended the CPUC adopt a 26.5% PRM during the months of January to May and a 23.5% PRM during the months of June through December, to maintain the target reliability level of 1 day in 10 years (0.1 LOLE). This recommended PRM is much higher than the originally set 17% PRM in the 2025 SOD implementation framework.
• September 9, 2024- CalCCA filed comments on the published RA LOLE study, urging the Commission to conduct further analysis before adopting the recommended PRM of 26.5% PRM during the months of January to May and a 23.5% PRM during the months of June through December. CalCCA cited concerns with potential study methodology flaws and significant impacts to ratepayer affordability associated with the recommended PRM.
• September 19, 2024- PG&E released their 2024 CPE Annual Compliance report. The report shows they are short in their centralized procurement of RA for 3 years forward. • October 29, 2024- The CPUC issued a PD for RA Track 2, which deals with the PRM and CPE framework.

Regarding the proposed PRM, the Commission agreed additional vetting and further analysis is needed, authorizing ED to undertake a further revision of the 2026 PRM analysis which will be considered in Track 3 of the proceeding. As for the CPE framework, the Commission successfully adopted CalCCA’s proposal to lock in CPE allocations one year earlier, giving LSEs more time to self-procure, along with various other revisions.
• November 18, 2024- CalCCA filed comments on the RA Track 2 PD, recommending that the CPUC recognize the significant impact that changes to the PRM can have on reliability and affordability, and allow for earlier adoption of the 2026 PRM if thorough analysis is completed by all relevant stakeholders in advance of the Track 3 timeline. CalCCA also urged the CPUC to adopt revisions to the CPE framework as outlined in the PD, with an opportunity to review their effectiveness at the end of 2027. • December 20, 2024- ED published another revised version of their RA LOLE study, recommending an updated 2026 PRM of 21% for the months of October to May and 22.5% for the months of June to September. Due to affordability concerns, ED also included two proposals to mitigate the adverse effects of the high PRMs. The first proposal entails adopting a 17% PRM as an RA requirement, paired with an effective PRM of 22.5% which only IOUs are required to comply with; this proposal would extend the current 2025 status quo. The second proposal entails adopting a 22.5% PRM, but with an option for LSEs to apply for temporary System Waivers in peak months (June to September) for requirements above a 17% PRM based on a cost threshold.
• January 17, 2025- CalCCA filed their RA Track 3 proposals, recommending the CPUC to allow LSEs to transact load obligations on an hourly basis, address co-located generation and RA needs, and incorporate the local RA CPE data request process into the existing RA filing rather than the IRP data collection process. • February 25, 2025- ED issued a correction to their LOLE study, updating their recommended 2026 PRM to 20% for the months of November to May (off-peak) and 21% for the months of June through October (peak). Under this new PRM, the two price mitigation proposals change accordingly. Proposal A entails adopting a 17% PRM as an RA requirement, paired with an effective PRM of 21% in the peak months of June through October, which only IOUs are required to comply with; this proposal would extend the current 2025 status quo. Proposal B entails adopting a 20% PRM for off-peak months and 21% PRM for peak months, paired with an option for LSEs to apply for temporary System Waivers in peak months for requirements above a 17% PRM based on a cost threshold.
• February 28, 2025- The CalCCA Board voted to support Proposal B, which would require LSEs to adopt an increased PRM of 20% in the off-peak months and a 21% PRM in the peak months, with the option of [Publish Date] Agenda Date: 9/18/2025

applying for a System Waiver in the peak months for obligations above a 17% PRM. • March 3, 2025- Opening comments were filed on the RA Track 3 Proposals. Most parties, except the IOUs, supported CalCCA’s proposals to adopt hourly load transactability and allow co-located energy only resources to count as RA under SOD. Furthermore, most parties opposed the price mitigation Proposal B which would allow for System RA waivers, and instead recommended the adoption of a PRM that will allow the grid to consistently meet the pre-determined target of 0.1 LOLE. • March 17, 2025- Reply comments were filed on the RA Track 3 Proposals. CalCCA urged the CPUC to reject arguments made by PG&E, SDG&E, and Middle River Power regarding the hourly transactability proposal. As for the proposed PRM and price mitigation proposals, CalCCA reasserted that the CPUC should adopt a 21% PRM in peak months, 20% PRM in off peak months, along with a system RA waiver option in peak months for obligations above a 15.5% PRM, as indicated by SCE’s independent PRM study. However, due to the ongoing disputes over a correct PRM to meet the 0.1 LOLE target, CalCCA urges the CPUC to continue refining their LOLE modeling for the upcoming 2027 PRM. • April 16, 2025 - CalCCA held ex-partes with CPUC Commissioners to continue advocating for adoption of the hourly load obligation trading proposal, setting the PRM at 21% in peak months and 20% in off-peak months with an option for system RA waiver for requirements above 15.5% consistent with Southern California Edison’s modeling results, and enabling increased co-located resource RA participation under the RA slice-of-day framework.
• May 22, 2025- The CPUC issued a PD adopting local capacity obligations for 2026-2028, flexible capacity obligations for 2026, and program refinements as proposed in Track 3 of the RA proceeding. Regarding the PRM proposals, the PD adopts an 18% binding PRM with extension of the effective PRM target of 3-5.5% for June to October, for the 2026 RA year. The effective PRM procurement target will be divided between the three IOUs based on the approximate CAISO load share. As for CalCCA’s proposals, the PD does not adopt hourly load obligation trading. Instead, the PD directs ED to conduct an evaluation after a full year of SOD implementation to assess the need, benefits, and feasibility of an hourly load obligation trading mechanism, by Q2 2026.
• June 11, 2025- Pioneer collaborated with Central Coast Community Energy (3CE) to file opening comments on the RA Track 3 PD, urging the Commission to reduce the effective PRM target from 3-5.5% to 3%, which when paired with the binding 18% PRM, is more in line with ED’s recommended total PRM of 21%. The comments also urge the Commission to reconsider adopting CalCCA’s hourly load transactability proposal, due to the abundance of supporting evidence on the record of its potential widespread affordability benefits.

In reply comments filed on June 16, 2025, multiple parties echoed Pioneer and 3CE’s argument for reducing the effective PRM target, to not exceed ED’s recommended PRM, based on intensive modeling/ study results. • June 27, 2025- The RA Track 3 final decision was approved at the CPUC voting meeting. The final decision did not incorporate the changes to the PRM or adoption of the hourly load transactability proposal as requested by Pioneer and 3CE in our opening comments to the PD.

Demand Flexibility:
• June 30, 2022- AB 205 passed giving the CPUC the authority to approve a pricing structure that incorporates an Income Based Graduated Fixed Electricity Charge (IGFC). • July 14, 2022- The Commission issued an OIR to begin this proceeding to establish demand flexibility policies and modify electric rates to advance the following objectives: 1) enhance the reliability of California’s electric system; 2) make electric bills more affordable and equitable; 3) reduce the curtailment of renewable energy and greenhouse gas emissions associated with meeting the state’s future system load; 4) enable widespread electrification of buildings and transportation to meet the state’s climate goals; 5) reduce long-term system costs through more efficient pricing of electricity; and 6) to enable participation in demand flexibility by both bundled and unbundled customers. • July 31, 2023- Parties submitted Comments on the IGFC Implementation Pathways considering the ALJ Ruling’s questions.
• August 21, 2023- CalCCA submitted Reply Comments to refute parties’ arguments regarding including the PCIA or Competitive Transition Charge (CTC) as fixed costs eligible for inclusion in the IGFC. [Publish Date] Agenda Date: 9/18/2025

• October 27, 2023- 22 Democratic lawmakers sent a letter to the CPUC asking for an extension of the timeline for the proceeding and require public participation hearings before implementing an IGFC. • November 3, 2023- Track A (IGFC)- CalCCA filed a reply brief continuing to refute party proposals that the PCIA be included in the IGFC and noting that the parties advocating for inclusion of the PCIA have not addressed the arguments put forth by CalCCA.
• December 15, 2023- Track B (demand flexibility)- The CPUC issued a PD which directs PG&E to expand the Valley Clean Energy Ag-Fit pilot program. CCAs that participate in the expanded pilot may receive $20/kW for each year of customer enrollment in the PGE Ag-Fit pilot as an incentive. The incentive is capped at $1.8 million for PG&E’s territory. The budgets are for all the CCAs wanting to participate to share. PG&E will be administering the pilot so there will be no administrative costs, but several of the CCAs want to have a say in how the pilot is administered and the education and outreach of the pilot. December 18, 2023- Track A (IGFC)- CPUC issued a ruling requesting implementation information from the IOUs on the IGFC. The ruling directs the IOUs to file additional information about the proposed budgets for implementing the first income-graduated fixed charges by January 24, 2024. • January 23, 2024- (Track B) There was a revised PD on the expanded pilots. Pioneer is considering offering the expanded Ag-Fit program to its customers. The pilot will be administered by PG&E so it will involve minimal work on behalf of Pioneer staff, but it will also bolster our Load Management Standards program and keep us competitive with PG&E.
• January 26, 2024- The CPUC approved the expanded pilots revised decision. In D.24-01-032 to Advance Demand Flexibility Through Electric Rates, the CPUC directed PG&E to expand the Valley Clean Energy Ag Real Time Pricing Pilot (VCE AgFIT Pilot). The decision orders PG&E to extend the duration and expand participation of the VCE AgFIT Pilot to agricultural customers throughout PG&E’s service territory. • January 30, 2024- (Track A)- There was a press conference held by a group of 20 Democratic Legislators calling for the repeal of income-graduated fixed charge. AB 1999 would repeal the income-graduated fixed charge approved under AB 205 (2022) and replace it with a $5 fixed charge for CARE customers and a $10 fixed charge for all other residential customers.
• February 13, 2024- Pioneer staff sent PG&E an email indicating interest in possibly participating in the expanded pilot expansion program, particularly the Ag Pilot. • February 13, 2024- At the Senate Utilities, Energy and Communications hearing the IGFC was brought up by CPUC president, Alice Reynolds, who indicated the CPUC was working on an IGFC decision possibly by the end of Q1.
• March 1, 2024- There is an expanded pilot workshop to address dual participation, since some demand flexibility programs prohibit dual enrollment. Dual Participation is allowed for- Critical Peak Pricing: (Peak Day Pricing and SmartRate), Electrification Rates: (E-ELEC), TOU Rates (E-TOU, E-TOU-D), Simple NEM and NBT, and ELRP Subgroup A: (A1-A6). Dual Participation is Prohibited- Supply-Side DR Programs (BIP, CBP, ART, DRAM, non-DRAM DR RA Contracts, DSGS Option 2), Flex Market Pilot, DAHRTP, ELRP Subgroup B:

B1-B2, and Other Event-Based Load-Modifying Programs (OBMC, SLRP). • March 25, 2024- PG&E submitted their Tier 2 AL for implementation plans for PG&E’s Expanded Ag Pilot. 5 CCAs have expressed an interest in participating in PG&E’s Ag Pilot in 2024 (Ava, SVCE, VCE, 3CE, and Pioneer). PG&E will launch the pilot in June of 2024. Participants will continue to pay their current bill and will receive the shadow bill, which they will not pay. The shadow bill will illustrate a customer’s potential savings under the dynamic pilot rate. There is also a $20 per unbundled kW per year incentive, subject to a $1.8 million cap for all CCA incentives.
• March 27, 2024- The CPUC issued a PD addressing AB 205 (Income Graduated Fixed Charge) requirements for electric utilities. The earliest this PD could be adopted is May 9, 2024. This decision authorizes all IOUs to shift the recovery of a portion of fixed costs from volumetric rates to a separate, fixed amount on bills without changing the total costs that utilities may recover from customers. As a result, this decision reduces the volumetric price of electricity (in cents per kilowatt hour) for all residential customers of IOUs. The CPUC did not adopt the IOUs’ proposal and instead the proposal would have Tier 1 (customers enrolled in CARE) pay $5 a month, Tier 2 (customers enrolled in FERA or who live in affordable housing restricted to residents with incomes at or below 80% of Area Median Income) pay $12 a month, and Tier 3 (all other customers) pay $24.15 per month. This new billing structure would apply to all residential rates of the IOUs, except for master-meter rates that are not sub-metered.
[Publish Date] Agenda Date: 9/18/2025

• May 9, 2024- CPUC approved implementation of the Income Graduated Fixed Charge without any changes to the structure described in the previous bullet.
• June 12, 2024- CalCCA filed reply comments on the Track B Proposal, urging the CPUC to reconsider the process for updating marginal cost values and to clarify a cost recovery structure that ensures CCA customers do not get double-charged for being unbundled.

PG&E ERRA Compliance and ERRA Forecast:
• The ERRA proceedings act as a review of an IOU’s prior year portfolio management and accounting and seeks to identify errors and discrepancies between PG&E’s revenue requirements vis-à-vis collected revenues through the IOUs’ General Rate Case (GRC) which ultimately affects CCA rates through the Power Charge Indifference Adjustment (PCIA).
• May 14, 2023- PG&E’s 2023 – 2024 ERRA Forecast and Testimony was released. • June 1, 2023- NewGen sent over the new rate forecast spreadsheet. The forecast looks good with the PCIA remaining negative over many vintages, but this will change before the October Update. • June 16, 2023- Keyes and Fox filed a Protest to PG&E's Forecast Application. • August 10, 2023- CalCCA filed a Protest to PG&E’s ERRA Trigger Application proposing a rate increase in November to correct and account for under-collections.
• September 6, 2023- CalCCA provided Testimony on the 2024 PG&E ERRA Forecast case and touched upon the fixed generation cost issue.
• October 16, 2023- PG&E’s October Update to its 2024 ERRA Forecast came out. Energy prices have softened relative to PG&E’s original forecast (which would, all else equal, cause PCIA rates to increase), but RA and RPS benchmarks have increased significantly since PG&E's filing (dampening the impact of energy prices).

All told, forecast rates increased relative to the original forecast across the board, but forecast rates remain negative for vintages 2021 and later.
• November 1, 2023- Keyes and Fox submitted comments on PG&E’s ERRA Trigger proposal and comments on PG&E’s October update.
• November 16, 2023- The CPUC unanimously approved the Alternate PD and indicated that “the decision balances a myriad of competing interests- affordability, feasibility, safety, and reliability.” PG&E requested $15.4 billion for 2023, and the decision reduced that amount by $1.8 billion to $13.5 billion. This is an 11% increase from the authorized 2022 revenue requirement. For the typical residential customer, their combined monthly electric and natural gas bill will increase by $32.62 or 12.8%, compared to PG&E’s request of $38.73 or 17.9% increase.
• November 30, 2023- The PD for the PG&E 2024 ERRA Forecast came out. There were a couple of disputed issues including whether to amortize the 2023 trigger balance over 6 months or 12. CalCCA was asking for 12 and PG&E was asking for 6 months. The CPUC adopted PG&E’s recommendation. The second issue was whether PG&E should apply a first-in-first-out methodology to the use of excess prior year RECs or a last-in-first-out methodology. The CPUC ruled with PG&E on a last-in-first-out methodology. • December 12, 2023- A revision to the PD came out and CalCCA won its argument on first-in-first-out, meaning the CPUC is requiring PG&E to use a first-in-first-out methodology for RECs banked in or after 2019.
• December 29, 2023- PG&E submitted their Annual True-Up to change PG&E’s electric rates on January 1, 2024.
• March 21, 2024- There was a Preliminary Issue Review with Keyes and Fox. The 2021 ERRA proceeding is still open but coming to an end, 2022 is still busy, and 2023 is just starting up. Some of the big issues to watch include PG&E’s RA Sales and Accounting; DWR reimbursement to PG&E; and Retained, Sold and Unsold RPS.
• June 12, 2024- The Assigned Commissioner issued the Scope Ruling in PG&E’s 2023 ERRA Compliance proceeding. The ruling does not adopt CalCCA’s recommendation to expressly clarify that the reasonableness of PG&E’s record year RA activities and sales is within the scope of this proceeding. It excludes the RA scoping issue out of this proceeding altogether, possibly in hopes the issue will be settled in PG&E’s 2022 ERRA Compliance proceeding. The Scope Ruling also lays out the procedural schedule. NewGen and Keyes & Fox will continue to work on discovery and reconvene with CalCCA before Intervenor testimony [Publish Date] Agenda Date: 9/18/2025

is due in September.
• June 17, 2024- CalCCA filed a protest to PG&E’s 2025 ERRA Forecast application. In this proceeding, the 2025 levels for the PCIA will be established. Due to forecasted low brown energy prices and high RA prices, the PCIA is expected to decrease, which will result in increased generation rates for PG&E’s bundled customers. PG&E’s 2025 ERRA Forecast application proposes a new ratemaking method to ensure reasonable rates for bundled ratepayers, by freezing the RA market price benchmark (MPB) at its 2024 forecast level, rather than using the 2025 forecast or the 2024 actual RA MPBs. CalCCA responded, urging the Commission against considering these broad policy questions, which fall outside the scope of the ERRA Forecast proceeding. CalCCA also argues that implementing an RA value cap would inappropriately inflate PCIA rates, shifting costs to unbundled customers, in violation of the PCIA ratemaking framework that has been established.
• July 25, 2024- The CPUC issued an ALJ ruling in PG&E’s 2022 ERRA Compliance proceeding, re-opening discovery to examine potential RA withholding actions taken by PG&E. • August 1, 2024- Assigned Commissioner issued a Scoping Memo and Ruling in PG&E’s 2025 ERRA Forecast application, supporting CalCCA’s protest that this proceeding is not the correct venue to address the RA MPB issue.
• September 3, 2024- CalCCA filed a direct testimony, prepared by Brian Dickman, in PG&E’s 2025 ERRA Forecast proceeding on behalf of CCAs. The testimony urges the CPUC to reject PG&E’s proposed change to its common cost allocation method and its proposal to create a new category of RPS-eligible resources outside of the previously recognized context of the PCIA calculation. The testimony also calls upon PG&E to make corrections to their calculation of “negative retained system RA” and “amount included as the amortization of the gain on the sale of its San Francisco General Office headquarters”. • October 4, 2024- CalCCA filed an opening brief, prepared by Keyes and Fox, in PG&E’s 2022 ERRA Compliance proceeding regarding the issue of PG&E withholding excess RA. CalCCA urged the Commission to revisit PG&E’s Bundled Procurement Plan in the IRP proceeding to ensure PG&E is making its excess RA available to the market in a timely and comprehensive manner, which is critical due to current RA market shortages. The brief incorporated the new discovery responses received from PG&E, once the ALJ re-opened the discovery window for CalCCA in July 2024.
• October 4, 2024- Energy Division released the 2024 Final MPBs and 2025 Forecast MPBs that are used to calculate the PCIA in PG&E’s 2025 ERRA Forecast proceeding. They have since issued corrections to the MPBs several times.
• October 8, 2024- In the PG&E 2025 ERRA Forecast proceeding, the ALJ issued an email ruling asking for comments regarding the impact of the recently released MPBs. The questions posed ask parties whether they expect the released MPBs to have a significant impact on the issues within the scope of the proceeding, and to offer any procedural options to address these impacts. • October 14, 2024- PG&E and CalCCA replied to the ALJ ruling asking for party comments relating to the impact of the released MPBs. PG&E stated the released RA MPBs will result in a $500 million increase to the bundled customer generate revenue requirement, while departed load customers would see a net reduction of $500 million through their PCIA. Furthermore, the released RPS MPB would increase the bundled service customer generation revenue requirement by an additional $250 million, with a corresponding reduction to departed load customers. For these reasons, PG&E asks the Commission to delay the procedural timeline and consider various mitigation methods such as producing additional rate-setting scenarios and establishing a tracking account to remediate any potential cost shifts while further investigating this issue.

CalCCA stated in their replies that the RA MPB is operating as the Commission intended, therefore, no modifications to the ratemaking process in this proceeding are warranted. CalCCA reiterated that proposals to modify the PCIA revenue requirement calculation methodology are outside the scope of this proceeding and should not be considered in response to the ALJ ruling. • October 23, 2024- PG&E filed their Fall Update, in which they argue the recently released MPBs were wrongly calculated and inflated. Considering how the high price of the RA MPB does not appropriately incentivize procurement compliance, PG&E urges the Commission to consider mitigation measures. They present various mitigation proposals which involve freezing the RA and/ or RPS MPBs to 2024 forecast levels [Publish Date] Agenda Date: 9/18/2025

and tracking the differences in a balancing account.
• October 31, 2024- CalCCA filed a motion to strike PG&E’s MPB discussion and mitigation proposals from the record, as they were already deemed out of scope for this proceeding in a previous ALJ ruling. CalCCA also filed a reply brief which reiterates that the Commission should not consider MPB mitigation measures in this proceeding and argues that the “gross revenue requirement” methodology equitably allocates common costs to customers.
• November 15, 2024- CalCCA held an ex parte and met with Maria Sotero from Commissioner Reynold’s office to discuss the MPB issues and better understand what strategies the CPUC wants to pursue in this case. The CPUC expressed understanding of CalCCA’s recommendation to maintain consistent usage of the MPB methodology in PG&E’s 2025 ERRA Forecast proceeding but did indicate a desire to open a new rulemaking to consider changes to the MPB methodology.
• November 15, 2024- PG&E submitted their Annual Electric True-Up to change PG&E’s electric rates on January 1, 2025.
• November 25, 2024- The CPUC issued a PD for the PG&E 2025 ERRA Forecast proceeding which maintained that PG&E’s RA mitigation proposal is out of scope, securing CalCCA’s win in preventing $1B in costs to the PCIA. PG&E was ordered to use the 2024 MPBs that ED released. However, the PD states that the CPUC may open a new rulemaking to consider modifications to MPB methodology, with possible retroactive rate collections in PG&E’s 2025 Annual Electric True-Up. Furthermore, the PD adopts PG&E’s common cost allocation proposal, but sides with CalCCA that the change should be applied prospectively in 2025 and forward, not to 2024 costs.
• December 2, 2024- CalCCA filed opening comments to the PD in PG&E’s 2025 ERRA Forecast proceeding, emphasizing the importance of providing adequate timelines and discovery rights for non-IOU parties in any future proceeding that will deal with modifications to the RA MPB methodology. Considering recent changes in the RA market including System RA scarcity and sharp price increases in short-term RA, CalCCA does not oppose revisiting the RA MPB methodology, but urges the Commission to consider a more comprehensive evaluation of the methodology. CalCCA’s comments also push back on the CPUC’s adoption of PG&E’s common cost allocation methodology and urges the CPUC to instead adopt CalCCA’s proposal based on gross revenue requirements.
• December 19, 2024- The CPUC issued a final decision in PG&E’s 2025 ERRA Forecast proceeding, bringing it to a close. The decision adopts PG&E’s revised proposal of common costs allocation beginning with January 1, 2025 rates. PG&E’s estimated 12-month net revenue requirement for 2025 is $2.25 billion, resulting in an expected decrease of bundled residential customers’ rates by 2% and a decrease of unbundled residential customers’ rates of 4.4%.
• December 30, 2024- PG&E filed their final Annual Electric True-Up, reflecting the CPUC’s final decision, to update their electric rates effective January 1, 2025.
• February 3, 2025- CalCCA filed an opening brief in the PG&E 2024 ERRA Forecast proceeding recommending that the CPUC should not modify the definition of fixed generation costs, which most other parties were in consensus with. CalCCA also encouraged the CPUC to address any changes in the common cost allocation methodology in a separate, non-expedited rulemaking with all three IOUs as parties, in order to ensure consistency in their practices.
• February 28, 2025- PG&E filed its 2024 ERRA Compliance Application. ERRA Compliance proceedings review PG&E’s activities in the prior year related to its ERRA and PCIA to ensure that those activities were reasonable and comply with Commission decisions and that associated accounts are accurate. • April 4, 2025 – CalCCA filed a Protest of PG&E’s 2024 ERRA Compliance Application, arguing that the Commission should set the matter for hearing to provide CalCCA an opportunity to analyze the application, including preliminary issues it identified concerning PG&E’s RA sales activities, PG&E contract amendments, changes to PG&E’s Retained RA Tracker, and PG&E’s treatment of “banked” renewable energy credits to meet its Renewable Portfolio Standard (RPS) requirement. CalCCA also argues that the Commission should explicitly include PG&E’s attempts to sell excess RA consistent with its Bundled Procurement Plan in 2024 within the scope of the proceeding.
• April 23, 2025 – The ALJ issued a PD in PG&E’s 2022 ERRA Compliance proceeding that found that issues [Publish Date] Agenda Date: 9/18/2025

concerning PG&E's sales or attempts to sell excess RA during the summer of 2022 are not relevant to issues in the proceeding. CalCCA will file comments on the PD pushing back on this finding given that the ERRA Compliance proceedings are the only venue we have to examine PG&E’s excess RA transactions. • May 2, 2025 – The ALJ in PG&E’s 2024 ERRA Compliance proceeding issued a scoping ruling that included CalCCA's request to include as an issue whether PG&E made reasonable attempts to sell excess RA consistent with its Bundled Procurement Plan. This Scoping Ruling conflicts with the 2022 ERRA Compliance PD, providing support for CalCCA’s arguments in comments on that PD. • May 15, 2025 – PG&E filed its 2026 ERRA Forecast application, which will, in part, establish the PCIA rate for 2026.
• June 11, 2025 – Keyes & Fox and NewGen convened a preliminary issue review regarding the PG&E 2026 ERRA Forecast application. From NewGen’s preliminary analysis, it is apparent that there will be a significant under-collection for Portfolio Allocation Balancing Account, which will have to be recovered through the 2026 PCIA, putting upward pressure on that rate. There are other issues that Keyes & Fox will litigate to potentially help ease the PCIA rate increase in 2026 (e.g., battery RA valuation, use of banked RECs, PG&E’s GHG free sales, etc.), but even if successful, that increase is expected to be significant. • June 18, 2025 – CalCCA filed a protest of PG&E’s 2026 ERRA forecast. The protest highlighted the issues discussed in the June 11, 2025 preliminary issues review regarding PG&E valuation of both pre-2019 banked RECs and the RA attributable to batteries in its PCIA portfolio. PG&E effectively values both at zero, which has the effect of increasing the PCIA.
• September 2, 2025 – CalCCA filed testimony in PG&E’s 2026 ERRA Forecast proceeding. The testimony went into detail on the two issues identified in CalCCA’s protest on pre-2019 banked RECs and valuing the RA attributes of battery storage, arguing that PG&E’s approach does not properly compensate unbundled customers for the value of resources procured on their behalf.

Provider of Last Resort (POLR):
• October 2, 2019- SB 520 passed requiring the establishment of a POLR. As part of the proceeding to implement SB 520, the CPUC is seeking to establish new policies to plan for and prevent catastrophic failures in the event of an unplanned return en masse of CCA customers to IOU service. Additionally, the CPUC will review and update existing procedures and policies for Financial Security Requirements (FSR), re-entry fees, and LSE de-registration process and compliance requirements. • July 31, 2023- CalCCA's Reply Briefs were submitted and address PG&E’s proposal to modify the FSR to reflect two months of forecast energy costs, other parties’ recommendations on elements of the existing FSR calculation, mandatory contract assignments, financial monitoring, and the duration of POLR service. • March 14, 2024- The CPUC issued a PD, with a mix of favorable and unfavorable decisions. For example, it rejected PG&E’s proposal to require FSR postings to reflect 2 months of POLR service, it maintains the ability to use service bonds, and it keeps confidential the information about LSEs that trigger financial monitoring.

However, the PD also approved using PG&E’s Administrative Fee ($4.24) without sufficient evidence of the costs, the CPUC should clarify that November 2024 FSR Calculation would be the earliest possible calculation under the new rules, and the CPUC should clarify the timing of the second tier of reporting requirements so CCAs know when to evaluate their metrics. The biggest issue the PD addressed was updating the FSR requirements. The minimum FSR remains $147,000, but now CCAs must use the IOU’s Administrative Fee multiplied by the number of accounts the CCA has, and post whichever amount is higher. For CCAs in PG&E’s territory the administrative fee is $4.24 per customer, while the other IOUs’ administrative fees are significantly less (around $.50 per customer). If the final decision requires CCAs within PG&E’s service territory to use PG&E’s administrative fee, all CCAs within PG&E’s service territory will likely be paying an FSR well over the $147,000 minimum.
• April 23, 2024- CPUC adopted a revised POLR Decision inclusive of several of CalCCA’s requests.

Specifically:
o Reducing RA costs in the FSR by accounting for returning CPE RA allocations, in addition to the CAM and DR RA allocations.
o Nets PCIA in the FSR whether the PCIA is positive or negative. o Affirms current timing for calculating FSRs.
[Publish Date] Agenda Date: 9/18/2025

o Provides CCAs with an additional 60 days to file first FSR following IOU tariffs implementing this decision.
o Requires CCAs to file the Tier 1 audited financial report to Energy Division once a year, in January or July, whichever comes earlier relative to the availability of the audited financial statement.
o Allows 90 days for CCAs to submit joint advice letter on new CCA registration process • July 12, 2024- CalCCA, on behalf of Pioneer, filed a Tier 2 AL to formalize the Financial Monitoring and Reporting Guidance document. The CPUC requires financial reporting to be done on a 2-tier system. Tier 1 requires every CCA to submit an annual audited financial report. Tier 2 requires CCAs to submit additional financial reporting, if certain trigger events such as a change in credit rating occur. This document clarifies the process and procedures CCAs must follow to comply with Tier 2 financial reporting conditions. o July 22, 2024- The joint IOUs filed a protest to the joint CCAs’ AL on Financial Monitoring and Reporting Guidance, insisting CCAs’ use “lines of credit” instead of “letters of credit” as the primary financial instrument to demonstrate days of liquidity of hand (DLOH). The IOUs also insisted CCAs report financial triggers 10 days after they occur, instead of the proposed 60 days.
o September 6, 2024- CalCCA met with Energy Division to express that CCAs agree to comply with the joint IOUs’ request to use “lines of credit” to calculate DLOH. On the issue of minimum days required to report financial trigger events, CCAs insist on keeping 60 days, as this is the minimum amount of time required to prepare accurate financial statements due to complex billing and accounting systems.
• July 17, 2024- CalCCA, on behalf of Pioneer, filed a Tier 2 AL to clarify requirements for the new CCA registration process and implementation plan. These requirements include (1) submission of a feasibility study and pro forma financial statement with the Implementation Plan, (2) establishment of annual assumptions to be included in the pro forma financial statement, (3) establishment of milestones for critical implementation action and review progress, and (4) submission of an updated proforma financial statement six months prior to launch. The AL served to provide additional examples for annual assumptions and critical milestones.
o August 6, 2024- PG&E filed a protest to the joint CCAs’ AL on additional implementation plan requirements, citing the proposal would limit the CPUC’s ability to assess whether enhancements to the implementation plan would result in cost shifts to bundled customers. o August 13, 2024- CalCCA filed a reply to PG&E’s protest on the additional implementation plan requirements, citing the additional requirements proposed are correctly slotted under the umbrella of CPUC authority to certify implementation plans and determine a cost-recovery mechanism for CCA customers that prevents cost shifts to bundled customers. • August 6, 2024- An ALJ Ruling was issued to define the scoping issues in Phase 2 of the POLR proceeding, which will be primarily concerned with clarifying requirements for an application for a non-IOU LSE to become the POLR.
• August 23, 2024- The prehearing conference for Phase 2 was held, in which CalCCA filed a statement agreeing with the current set of questions proposed in the Phase 2 scope. In its statement, CalCCA also urged the CPUC to reject PG&E’s request to scope in issues regarding the liquidity needs of the POLR and analysis of seasonal RA pricing.
• October 24, 2024- The CPUC issued a scoping ruling for Phase 2 of the POLR proceeding which sets two primary topic areas. The first is establishing the regulatory framework for non-IOU POLRs and the second is the development of the joint application for a non-IOU LSE to serve as POLR. • November 12, 2024- The IOUs filed their ALs for the bi-annual FSR updates. CalCCA compiled the IOU ALs and confirmed they all made their FSR calculations consistent with the current authorization. Given that the IOU ALs implementing Phase 1 are still pending resolution, the FSR updates use the methodology in place without the Phase 1 Decision modifications. Due to the hold on the ALs, all CCAs will be obliged to post the minimum FSR of $147,000 come January 1, 2025.
• November 26, 2024- The CalCCA Regulatory Committee voted in favor of CalCCA engaging in Phase 2 of the POLR proceeding on behalf of its members, to ensure CCAs have a voice in the discussion for how a non-IOU [Publish Date] Agenda Date: 9/18/2025

POLR will be established and regulated. CalCCA will present the results of the Regulatory Committee’s vote to the Executive Committee on December 3, 2024, and to the CalCCA Board on December 12, 2024. • December 12, 2024- CalCCA’s Board of Directors voted to engage in Phase 2 of the POLR proceeding. • January 10, 2025- Opening comments were filed on the CPUC’s Phase 2 threshold questions. No IOUs expressed interest in transferring their POLR responsibilities. However, all three IOUs argued that any non-IOU LSE that serves as POLR should be subject to full CPUC jurisdictional authority. Furthermore, no non-IOU LSEs expressed interest in becoming the POLR, except for Shell Energy who only wants to serve commercial and industrial customers.
• January 24, 2025- CalCCA filed reply comments on the CPUC’s Phase 2 threshold questions, recommending the CPUC to establish a core framework for non-IOU LSE requirements and joint application process, but stopping short of building out the entirety of the framework due to the current lack of interest by parties in the designated POLR role. CalCCA also rejected arguments regarding the need for broad jurisdictional CPUC authority of a designated POLR.
• April 28, 2025- The CPUC approved PG&E’s AL 7326-E and 7326-E-A, allowing PG&E to update the FSR methodology. The decision implemented by this AL also now requires CCAs to post the greatest value out of the minimum requirement of $147,000, the per-customer administrative fee (# accounts * $4.24 for PG&E), or the FSR calculation. CCAs will have 60 days after the IOU POLR informs us of our new FSR calculation to complete our first FSR posting. After that, it will return to the normal deadlines of January 1 and July 1.

Changes to the FSR methodology include:
o Use the CPUC’s RA MPB to value RA, instead of the current RA Report by ED o Use the IOU POLR’s system average residential and nonresidential customer generation rates, instead of the system average rates
o Account for CCA customers’ allocation of RA from the IOU POLR’s cost allocation mechanism (CAM), central procurement entity (CPE) allocations, and demand response (DR) resources o Remove revenues from PCIA rates of CCA customers from the IOU POLR’s generation revenues
o Incorporate seasonal generation rates
o Remove the netting of negative procurement costs against the incremental administrative costs
• May 12, 2025- PG&E sent Pioneer our FSR calculation worksheet and advice letter. The materials indicate Pioneer must post the new FSR minimum of the per-customer admin fee. Pioneer has posted our balance to reflect our new FSR minimum.
• May 28, 2025- An ALJ issued a ruling proposing a procedural pathway for Phase 2. Due to lack of interest from non-IOU entities in assuming the POLR role, as indicated in the Phase 2 opening comments, the ALJ ruling proposes for the CPUC to issue a decision providing a framework for its regulatory authority over a non-IOU POLR and the services it provides. That decision would then close the current proceeding, and direct any non-IOU entity seeking POLR status to file a Petition for Rulemaking at least 12 months before filing an application to assume POLR responsibilities. The Commission would then resume consideration of threshold questions and topic areas set forth in the Scoping Memo. The ALJ ruling also seeks comments on proposed definitions regarding “POLR services”, to inform the framework around CPUC regulatory authority over a non-IOU POLR entity.
• June 13, 2025- CalCCA filed opening comments on the ALJ ruling, supporting the proposed procedural pathway for Phase 2. As for the proposed definitions regarding “POLR services”, CalCCA clarifies that the Commission need only to adopt a definition for “POLR-specific services”, because defining “Full-severable services” or “Non-severable services” is unnecessary as they are not within the Commission’s jurisdiction according to existing regulation and statute. CalCCA emphasizes that any POLR framework must preserve the protected autonomy of non-IOU LSEs by limiting the CPUC’s jurisdiction to POLR-specific services. • June 20, 2025- CalCCA filed reply comments on the ALJ ruling, responding to opening comments from parties including Cal Advocates, PG&E, SDG&E, and SCE, which try to unreasonably assert broader CPUC jurisdiction over non-IOU LSE POLRs.
[Publish Date] Agenda Date: 9/18/2025

Utility De-energization, PSPS, and EPSS:
• July 12, 2022-Pioneer, along with Joint CCAs, Joint Local Governments, and Rural County Representatives of California (RCRC), filed a motion with the CPUC on July 12, 2022, to consider EPSS issues in the De-energization or its own Proceeding. The arguments in the motion seek to treat EPSS events with the same regulations and oversight as Public Safety Power Shutoff (PSPS) events. • September 21, 2023- The CPUC approved a PSPS citation program for violations of the established PSPS guidelines.
• August 30-31, 2023- PG&E provided a post PSPS report. A total of 3,928 customers were deenergized. • October 10, 2023- The Joint CCAs, RCRC, and Joint Local Governments had a meeting with the Public Advocates Office to see if there is agreement on the need to further do more with regards to Fast Trips. The Public Advocates Office indicated that the CPUC and Office of Energy Infrastructure Safety are not inclined to act to regulate Fast Trips and that more data is needed. The Public Advocates Office is looking to submit a report in the beginning of 2024.
• January 16, 2024- The data for December’s Fast Trips and YTD data came out. These are the following circuits in Pioneer’s territory with 8 or more outages in 2023:
o Placerville 2106 (EDC)- 19
o Apple Hill 2102 (EDC)- 18
o Shingle Springs 2109 (EDC)- 11
o Mountain Quarries 2101 (EDC)- 11
o El Dorado PH 2101 (EDC)- 11
o Clarksville 2104 (EDC)- 9
o Apple Hill 2104 (EDC)- 9
o Lincoln 1101 (Placer)- 8
o Penryn 1103 (Placer)- 8
o Penryn 1107 (Placer)- 8
o Brunswick 1105 (Nevada)- 17
o Brunswick 1106 (Nevada)- 15
• January 29, 2024- A data request was made by joint CCAs (including Pioneer) using the circuits listed above to PG&E requesting the number of customers served by each circuit, the number of life support customers, the number of medical baseline customers, and the number of critical facilities served by each circuit. • March 8, 2024- Part of the information we were seeking regarding the data request came back. Pioneer staff will be reviewing this information.
• August 23, 2024- PG&E completed our data request made in January, except for information regarding hardening projects on the circuit including their pole numbers, project location and timeline, and type of hardening work to be completed, on the grounds these questions are out of scope and are unduly burdensome. Pioneer staff will be reviewing the rest of the data request provided. • May 8, 2025 – The CPUC will host a workshop regarding outage data collection, specifically focusing on data definitions and reporting.
• August 22, 2025 - Commissioner Baker and the Administrative Law Judge issued a ruling revising the scoping memo and schedule for Track 1 (outage reporting) of the safety and reliability proceeding. As it currently stands, the parties have submitted comments on the utilities’ current outage reporting and changes they would like to see, and the CPUC held a workshop during which our coalition presented our recommendations. The original plan for CPUC staff to issue a staff proposal for a revised set of reporting requirements, which would then be the subject of another workshop and opening/reply comments. The new plan is for the large utilities to submit a joint draft customer reliability report template by October 31, after which parties can file opening and reply comments on the proposal by November 14 and December 3, respectively.

CEC Load Management Standards (LMS):
• October 12, 2022- The CEC adopted the Load Management Standards regulation which requires the development of a statewide standard tool for authorized rate data access by third parties that is compatible with each IOU, large POUs, and large CCAs with the idea that electricity customers or their authorized third- [Publish Date] Agenda Date: 9/18/2025

party agents can look at rates that the customer is eligible to switch and allow the customer to change the customer’s current rate to rates they are eligible for. • June 8, 2023- CEC staff provided a schedule of the key LMS adoption and compliance dates. • August 1, 2023- Pioneer, through Calpine, uploaded its rates and will continue to work with Calpine on uploading all time dependent rates to meet deadlines.
• January 17, 2024- Workshop on implementation of LMS. Comments on the workshop are due on January

31. • March 21, 2024- Pioneer’s LMS plan presented to the Pioneer’s Board for approval. • March 26, 2024- Pioneer submitted the Board-approved LMS plan. • April 1, 2024- All large CCAs are required to file their plan for compliance with LMS regulations. • April 16, 2024- CEC held a scoping meeting to discuss development of the statewide rate access tool.

Discussions on how the tool will be funded are ongoing. • May 31, 2024- CPUC granted PG&E’s request to delay commencement of enrollment in its dynamic rates pilots from June 1, 2024 to November 1, 2024.
• July 15, 2024- The CEC requires LSEs to jointly develop and submit a Single Statewide Tool (SST) for their review by October 1, 2024. The joint IOUs, led by SDG&E, released a 50-page draft of a proposed model for the SST, and will host weekly workshops to receive input from CCAs and POUs. • September 4, 2024- Pioneer met with CEC staff to receive feedback on our LMS Compliance Plan and discuss the development of our LMS programs.
• October 1, 2024- In compliance with LMS regulation requirements, Pioneer filed the Single Statewide Tool concept design, terms and conditions, and pleading document, jointly with the IOUs, Large CCAs, and POUs.

In addition, Pioneer submitted our individual LMS Load Flexibility Programs List to the CEC. • January 17, 2025- CalCCA filed comments on the LMS docket, urging the CEC to pause its LMS implementation and assess next steps in regard to the necessity for LMS requirements and funding for the SST development.
• February 21, 2025- A small group of CalCCA Directors met with CEC Commissioner McCallister to discuss issues with the current application of LMS regulations by CEC staff, including how inconsistent the regulations are being applied among different CCAs and the steering of certain outcomes versus a non-biased review process based on economic and technological feasibility. Commissioner McCallister stated his intentions to work with his LMS staff to expedite CCAs’ LMS Compliance plans for approvals through increased flexibility.
• March 5, 2025- Pioneer corresponded with CEC LMS staff regarding program development in our LMS Compliance Plan. We provided an update that our LMS programs are not currently set up to connect price signals to the CEC’s MIDAS system, which is currently not functioning well per an operations update from our vendor who handles MIDAS interactions, Calpine. Pioneer will continue to monitor the situation to see if it is technologically and financially feasible to add this component of MIDAS price signals to our LMS programs in the future, when the MIDAS system issues are resolved. • May 8, 2025- The CEC, in a business meeting, will vote to delay the SST submission until May 8, 2026. • June 19, 2025- The CEC issued a formal revision request letter to Pioneer regarding our LMS Compliance Plan, which we are directed to revise to, in part, commit to offer the hourly flexible rate pilot programs of PG&E. The CEC directs us to file our board-approved revised plans by September 17, 2025 or 1 week following board approval of the revised plan.

Power Charge Indifference Adjustment (PCIA):
• February 20, 2025- The CPUC issued a new rulemaking to update and reform ERRA and PCIA policies and processes. This rulemaking was created as an avenue to deal with the RA MPB issue in the previous PG&E ERRA 2025 Forecast, where PG&E argued a new RA MPB methodology is needed to bring down the price.

Track 1 of the proceeding will consider changes to the RA MPB calculation on an expedited basis, aiming to implement the updated methodology in the upcoming October release of the annual MPBs. Track 2 of the proceeding will consider broader issues including review of revisions to the MPBs, evaluating need for ERRA- [Publish Date] Agenda Date: 9/18/2025

specific implementation guidance for RA program changes including SOD, how to reduce rate volatility, additional guidance for vintaging resources, and evaluating need for changes to bundled procurement plan processes. All CCAs are named as individual respondents, but all CCAs will file our responses collectively under CalCCA.
• March 18, 2025- CalCCA filed opening comments on the PCIA OIR, arguing that the CPUC has an obligation to both bundled and unbundled customers to administer the PCIA framework fairly and accurately, to ensure indifference. CalCCA included arguments that caution the CPUC against making changes to the PCIA framework or MPB methodology that would only serve to benefit bundled customers in current market conditions, which is considered a cost-shifting, not affordability measure. CalCCA also commented on the five RA MPB revision proposals set forth by ED, advocating for the CPUC to (1) reject including historic RA transactions in the RA MPB, (2) utilize a single RA MPB incorporating system, flex, and local values, (3) exclude affiliate transactions from the RA MPB, (4) exclude swap and sleeve transactions from the RA MPB, and (5) utilize monthly values for the RA MPB, instead of the current annual one to more accurately reflect seasonality. Opening comments by the Joint IOUs argued to include revisions to the RPS MPB in Track 1, as well as requesting the CPUC to consider the issue of their portfolio management and negative PCIA rates. • April 2, 2025- CalCCA filed reply comments on the PCIA OIR, reasserting the CCAs’ positions on the RA MPB revision proposals, and arguing that the Joint IOUs’ proposals to incorporate RPS MPB revisions and portfolio management concerns are not within the scope of Track 1, and the issue of negative PCIA rates should not be re-opened altogether.
• April 8, 2025- The Scoping Ruling for Track 1 was issued, setting a narrow focus on revisions to the RA MPB methodology, including the consideration of incorporating historic RA transaction data, combining of system, local, and flex values, and eliminating transactions that are duplicative or not reflective of market-based transactions. The Joint IOUs’ proposal to consider revisions to the RPS MPB, portfolio management, and negative PCIA rates were not included in the Track 1 scope. The ruling directs all parties to address the issue of retroactive rate setting in their opening briefs, making an argument on whether it is appropriate to apply a revised RA MPB methodology to the 2025 ERRA true-up. The ruling aims to produce a Track 1 PD by May 2025 and final decision by June 2025.
• April 21, 2025 - Parties submitted opening briefs. The briefs were largely legal arguments, with CalCCA arguing that application of any changes to the RA MPB to true-up 2025 rates is not allowed under the prohibition against retroactive ratemaking and that any decision must be supported by substantial evidence and narrowly tailored to the supposed transaction volume problem. The IOUs also filed testimony with substantive arguments supporting their position that the CPUC should look at historic RA transactions when determining the RA MPB.
• April 23, 2025 - CalCCA filed an opposition to the IOUs' motion to admit testimony, arguing that such testimony is inconsistent with the procedures established by the Administrative Law Judge and prejudices other parties.
• April 30, 2025 - Parties filed reply briefs primarily focusing on the legal arguments and the issue of whether to include historic RA transactions in the calculation of the RA MPB. CalCCA also filed its own testimony in response to the IOUs'. This may create a procedural and due process problem for the CPUC that could possibly delay a decision.
• May 23, 2025 – The Administrative Law Judge issued a PD on Track One of the PCIA rulemaking. If adopted by the Commission, the PD would make a variety of changes to the RA MPB methodology intended to make the result of that calculation more representative of RA value. Many of the changes were generally agreed upon by parties, including eliminating non-market transactions and combining the three different RA products (local, flex, and system) into a single RA MPB calculation. The most controversial change regarded whether to include more historical transactions and, if so, from how far back. The PD would include transactions up to four years prior. The PD would also apply all these changes to true-up currently effective 2025 rates, which will create a significant under-recovery that will have to be collected in 2026 rates, increasing the PCIA. In comments on the PD, CalCCA will oppose both the four-year historic transaction period and the application of the revised RA MPB to 2025 rates. • June 27, 2025 – The CPUC issued a Final Decision adopting the PD on Track 1 of the PCIA rulemaking. As described above, the effect of the decision will decrease the value of the IOU’s generation resources in rates effective in 2025, which will increase the 2025 PCIA under-collection. That under-collection will need to be [Publish Date] Agenda Date: 9/18/2025

recovered in the 2026 PCIA rates, increasing that rate for Pioneer’s customers. • July 28, 2025 – CalCCA filed an application for rehearing of the Track 1 Final Decision, requesting that the CPUC reconsider its decision to apply the revised RA MPB to 2025 PCIA rates. CalCCA argues that the CPUC’s Final Decision commits legal error because application of the RA MPB to 2025 PCIA rates violates the prohibition against retroactive ratemaking.
1 Attachment 3: Communications, Outreach & Customer Care Updates Date: 9/18/2025
NOTABLE ACHIEVEMENTS –JULY/AUGUST 2025
• Pioneer continues to grow its community presence,
with participation in more than two dozen events
during July and August, including hosting two
successful contractor events to educate area
contractors about Pioneer’s programs and benefits.
• Customer satisfaction continues to rise, with high
marks on post-call and chatbot surveys and a 3.9-
star average on all Google reviews.
• Staff completed a data-driven “refresh” of the
website and marketing materials to include
information about expansion, and an ability to
integrate current topics and up-to-the-minute
messaging.

WEBSITE
Website visitors continue to look at our Programs
pages, which have consistently dominated the most
frequently viewed pages in recent months. However, most visitors began at the home page during July and August. Top pages views were:

1. Home Page

2. PowerShift Rewards

3. AC Tune Up

4. GridGen

5. Residential Programs
The majority of the site traffic was generated directly from e-blasts originating from Pioneer, as well as from organic searches. A mailer focused on money-saving programs drove traffic to our site. There was a notable spike in website traffic on the day an eblast was sent, with more than 2,000 users on that day alone.

PIONEER IN THE COMMUNITY
Events and sponsorships, public presentations, and program support were added to Pioneer’s schedule of regular outreach events, with a presence at more than two dozen community events including:

Sponsorships
• Auburn Chamber 4th of July Event
• Lincoln Chamber 4th of July Parade
• Grass Valley Chamber 4th of July Event
• Nevada County Fair Sponsorship
• Wing & Wheels event at Lincoln Airport
Programs support
• Town of Loomis presentation
• Clean Fleet Revenue Program meetings with Auburn, Nevada City, Loomis Plf)NEER

COMMUNITY ENERGY

3.9 *** 106 Google reviews
• ? reviews
***** a day a(JO NEW
Everyone was so pleasant and welcoming when I stopped by. Happy employees .. , happy company! 0 Hover to react <
• Margaret Kellas
1 review
***** adayago NEW
people at Pioneer are very accomodating and helpful. I made a mistake on an application, and they were understqnding and allowed me to correct it. took up three times their time, so, thanks. 0 Hover to react <
Jan Johnson
Local Guide · 199 reviews 165 photos
***** 5 days ago NEW
Great program to refund HVAC tune-up. A/C runs better and more efficiently saving energy and some of my expenses. Love it !

• Letter to Agricultural Commissioners regarding Hourly Flex Pricing Program Field Days were held to connect directly with customers were held at the Auburn Senior Center and in Shingle Springs.

Contractor outreach events were held in Rocklin and El Dorado Hills to help educate customers about Pioneer, our solar offerings, and programs. Nearly two dozen contractors attended the events.

Chamber involvement and support
• Meeting with El Dorado County Chamber CEO and President • Rocklin Chamber Sunrise Meeting
• Rocklin Chamber BOD Meeting
• Rocklin Chamber Government Relations Committee meeting • El Dorado Hills Chamber Lunch
• El Dorado County Chamber Business Lunch meeting
• Lincoln Government Relations Committee Meeting
• Loomis Chamber Meeting
Community presentations and events
• Sheridan Community Forum/MAC Meeting
• Grass Valley Farmers’ Market
• Rural Lincoln Community Forum
• Quarterly Loomis Joint Economic Development/Government Affairs • Rocklin Chamber Breakfast Meeting
• Attend City of Rocklin City Council Meeting, Clean Fleet Expansion
There is continued interest in joining Pioneer. Staff has provided background-only information to interested parties, as well as new leadership in expansion communities, including:
• Informational meeting with the Interim Yuba City Manager • Informational meeting with City of Colusa City Manager, resulting in a letter of intent and request for PG&E data
• Informational briefing with Madera County Economic Development Commission • Informational briefing with Shasta County Supervisor Matt Plummer • Informational briefing with Shasta County CAO David Rickert and staff member To better familiarize new members with Pioneer and ensure continuity of message, staff created talking points and shared a social media toolkit with all October 2027 expansion territories.

CUSTOMER CARE
The summer months have been busy for the Customer Care team, with:
• 894 calls in July (up 49% from June)
• 654 calls in August
• Rebates, questions about programs, and NEM were the leading topics, with high traffic days corresponding to various mailers and marketing efforts
• There were 17 re-enrollments during this same time frame • Significantly, opt-outs have decreased by 50 percent year-to-year The Customer Care team continues to focus on excellence in service, which is reflected in 95 percent satisfaction rate in completed surveys.

Chatbot
The chatbot had a total of 1,767 interactions during the July-August time frame, resulting in 169 live conversations and an average satisfaction rating of 4.5 out of 5 in satisfaction surveys.

SOCIAL MEDIA
Pioneer’s expansion generated considerable opportunity to create engagement and elevate our social media profile, with the sharing of news articles, tagging new and existing members, and captivating graphics.

PAID ADS
Radio ads ran in staggered flights (two weeks on/two weeks off) on Public Radio KVMR-FM, The Breeze (KBEB), The River (KYVR), The Mix (KYMX), and New Country 105.1 (KNCI). Station selection represents the best opportunities to reach a large cross-section of Pioneer’s service area.

Ongoing paid ads appeared on digital display, local sales sites, mobile ads, paid search, NextDoor and paid social media, generating nearly 3.8 million impression and 24,863 clicks to the website to date.

GridGen creatives performed best this period with the most clicks and highest click-through-rates.

See insights and ads
0 County of Butte and 1 other
rfJ Like

PIC)NEER COMMUNITY ENERGY
Reduce
Your
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Energy
Costs
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Hourly Flex Pricing for Agriculture Eorn lncentiVes. sove money, and suppon cleoner energy A91ieultural C\JS:lomel'S can cul energy costs by
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CJWfJV from peak pnces with lhls pilol program.
learn more and enroll today at
Pionff.-Community(nergy.org/Hourtyfle•Priclng
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Pioneer Community Energy to serve Paradise, Chico, and more by 2027 Pimeer Communitv El'lef'QY is exi>andinQ to 13 new Northern Cal,fomia communities bv Octob. ..

See il15ights and ads
0 El Dorado County Chamber of Commerce and S 01hers
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Contractors Event ~ El Dorado County
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0 El Dorado County Chamber of Commerce
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Attachment 4: Program Updates
Date: 9/18/2025

• 1,516 applications received to date.
• El Dorado, Lincoln and Rocklin customers have the largest number of program participants. • 194 contractors participating in program to date.
• Contractor events held on July 16 in Placer County and August 13 in El Dorado County. o These events were created to cultivate an increased understanding of our programs and build partnerships with local contractors in our service area and were well attended. • Supported by direct mail, paid advertisements, and on-site promotion at events. • Applications close October 1, 2025.
• The expansion of the GridGen program now includes
o Battery retrofit
o CARE/FERA offering for income qualified customers
o Accessibility to commercial and industrial customers
• Pioneer has generated a total of 276 leads, though not all leads follow through on system installation. o 87 customers in the active pipeline
o 11 customers achieved permission to operate
o 12 customers signed contracts
• Direct mailers, updated ad campaign, newsletter and other marketing efforts underway. • Customer testimonials are being collected to support marketing efforts. • First C&I contract.
• Contractor outreach and c-branded marketing materials have proven to be a highly effective marketing tool.
• Season runs through October 31, though enrollment is available year round. • Moderate summer temperatures have limited the number of “events” called to five • More than 1,400 enrolled customers.
• 1.4 MWh energy reduction, ~500 kW load shed.
• Direct mailers, postcards, newsletter/email campaigns, paid and earned social media support this program.

Ice Energy Storage (ice technology used for AC energy reduction) • 22 Participation Agreements under review
o ~130 units would be installed
• Ice Energy team has conducted:
o More than 200 site visits
o 35 site surveys
o 100+ Active leads
• Marketing efforts underway including promoting at all area Chambers of Commerce, direct mail, and newsletters
• Placer County and the City of Rocklin are considering potential projects.

Plf)NEER

COMMUNITY ENERGY
a\ AC TUNE-UP
\.V REBATE
@ GRIDGEN
© POWERSHIFT

REWARDS
Agenda Item: 1a Agenda Date: 9/18/2025

Clean Fleet Revenue
• Program is active with outreach to all existing member agencies. • Staff has met and/or connected with Cities of Rocklin, Nevada City, Auburn, Lincoln, Placerville, Loomis and both counties. Rocklin approved resolution to participate in program. • Discussions also include potential opportunities for additional municipal EV charging development.

Hourly Flex Pricing Pilot (credits for energy conservation for Ag customers) • Two customers enrolled in the program (19 meters/accounts). • The program is administered by PG&E.
• Application period closed abruptly in spring but then reopened for interested customers due to CCA concerns; however, incentive funding may soon reach capacity/limited. • First Pioneer customer “shadow bill” was received in August and generally reflects significant customer savings.

Online Marketplace (solar and/or battery storage purchasing) • Twenty-one (21) leads have been generated through the Electrum Marketplace • Staff will continue to evaluate opportunities to improve uptake in the program LED Discount (discounted LEDs at local hardware stores) • Roughly 75% of the allocated budget for this program has been used. o Participants include 21 independent retailers and seven Dollar Tree stores, bringing the total number of participating stores to 28.
• This program continues to remain popular, with retailers providing positive feedback and continuing to provide Pioneer marketing and visibility through community partnerships.

Community Advisory Committee
• The Community Advisory Committee (CAC) met on August 27, 2025. The agenda included a comprehensive program review; discussion about the recently release Joint Rate Mailer (JRM) and Green 100; and ideas for 2026 programs.

Pacific Gas and Electric Company
P.O. Box 997320
Sacramento, CA 95899-7320
We support your power to choose
As part of our mutual commitment to support your energy choice, Pioneer Community Energy (Pioneer) and Pacific Gas and Electric Company (PG&E) have partnered to provide you with a comparison of typical residential electric rates, average monthly charges and generation portfolio contents.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466.
®
Plf)NEER

COMMUNITY ENERGY
Understanding your energy choice
2025 Residential Electric Rate Comparison, E-TOUC* Standard Green100 Generation Rate ($/kWh) $0.17522 $0.13659 $0.14747
PG&E Delivery Rate ($/kWh) $0.29547 $0.29547 $0.29547
PG&E PCIA/FF ($/kWh) -$0.02197 $0.01178 $0.01178
Total Electricity Cost ($/kWh) $0.44872 $0.44384 $0.45472 Average Monthly Bill ($) $279.59 $276.55 $283.33
*This compares electricity costs for an average residential customer in the Pioneer/PG&E service area (Placer County) with an average monthly usage of 623 kilowatt-hours (kWh). This is based on a representative 12-month billing history for all customers on E-TOUC rate schedules for PG&E’s and Pioneer’s published rates as of March 1, 2025.

Generation Rate is the cost of creating electricity to power your home. The generation rate varies based on your energy provider and the resources included in your energy provider’s generation supply.

PG&E Delivery Rate is a charge assessed by PG&E to deliver electricity to your home. The PG&E delivery rate depends on your electricity usage, but is charged equally to both Pioneer and PG&E customers.

PG&E PCIA/FF The Power Charge Indifference Adjustment (PCIA) is a charge to ensure that both PG&E customers and those who have left PG&E service to purchase electricity from other providers pay the above market costs for generation resources that were procured by PG&E on their behalf. “Above market” refers to expenditures for electric generation resources that cannot be fully recovered through sales of these resources at current market prices. PG&E acts as a collection agent for the Franchise Fee (FF) surcharge, which is levied by the California Public Utilities Commission on behalf of cities and counties in PG&E’s service territory for all customers. PG&E bundled customers pay the PCIA and FF fees associated with the most currently available vintage year. PG&E charges Pioneer customers the PCIA and FF fees based on the year that they transitioned to Pioneer service.

Visit pioneercommunityenergy.org for more information.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466. ©2025 Pioneer Community Energy. All rights reserved. “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation. ©2025 Pacific Gas and Electric Company. All rights reserved. 6.25 CCC-062025-5391 Electric Power
Generation Mix* Standard Green100***
Specific Purchases Percent of Total Retail Sales (MWh)
Renewable 22.9% 41.9% 100.0%
•Biomass & Biowaste**** 2.6% 2.9% 0.0%
•Geothermal 0.3% 4.0% 26.7%
•Eligible Hydroelectric 1.5% 4.7% 36.7%
•Solar Electric 14.1% 25.9% 0.0%
•Wind 4.4% 4.5% 36.7%
Coal 0.0% 0.0% 0.0%
Large Hydroelectric 12.5% 4.2% 0.0%
Natural Gas 1.9% 0.0% 0.0%
Nuclear 62.8% 0.0% 0.0%
Other 0.0% 0.0% 0.0%
Unspecified Sources of Power** 0.0% 53.8% 0.0%
TOTAL 100.0% 100.0% 100.0%
*As reported to the California Energy Commission’s Power Source Disclosure Program. Data is subject to an independent audit and verification that will not be completed until later in 2025. The figures above may not sum up to 100 percent due to rounding.
**Unspecified sources of power refers to electricity that is not traceable to a specific generating facility, such as electricity traded through open market transactions. Unspecified sources of power are typically a mix of all resource types, and may include renewables. ***Power mix is estimated for 2025, is subject to change, and will be verified with the 2025 PCL.
****3 percent of retail sales is covered by Unbundled RECs.

For information, visit:

Para detalles de este programa en español, visite:
參閱本計劃中文版本, 請上網:
pioneercommunityenergy.org
Pacific Gas and Electric Company
P.O. Box 997320
Sacramento, CA 95899-7320
We support your power to choose
As part of our mutual commitment to support your energy choice, Pioneer Community Energy (Pioneer) and Pacific Gas and Electric Company (PG&E) have partnered to provide you with a comparison of typical residential electric rates, average monthly charges and generation portfolio contents.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466.
®
Plf)NEER

COMMUNITY ENERGY
Understanding your energy choice
2025 Residential Electric Rate Comparison, E-TOUC* Standard Green100 Generation Rate ($/kWh) $0.17373 $0.13508 $0.14596
PG&E Delivery Rate ($/kWh) $0.28550 $0.28550 $0.28550
PG&E PCIA/FF ($/kWh) -$0.02197 -$0.01781 -$0.01781
Total Electricity Cost ($/kWh) $0.43726 $0.40277 $0.41365 Average Monthly Bill ($) $276.97 $255.12 $262.01
*This compares electricity costs for an average residential customer in the Pioneer/PG&E service area (El Dorado County, Grass Valley and Nevada City) with an average monthly usage of 633 kilowatt-hours (kWh).

This is based on a representative 12-month billing history for all customers on E-TOUC rate schedules for PG&E’s and Pioneer’s published rates as of March 1, 2025.

Generation Rate is the cost of creating electricity to power your home. The generation rate varies based on your energy provider and the resources included in your energy provider’s generation supply.

PG&E Delivery Rate is a charge assessed by PG&E to deliver electricity to your home. The PG&E delivery rate depends on your electricity usage, but is charged equally to both Pioneer and PG&E customers.

PG&E PCIA/FF The Power Charge Indifference Adjustment (PCIA) is a charge to ensure that both PG&E customers and those who have left PG&E service to purchase electricity from other providers pay the above market costs for generation resources that were procured by PG&E on their behalf. “Above market” refers to expenditures for electric generation resources that cannot be fully recovered through sales of these resources at current market prices. PG&E acts as a collection agent for the Franchise Fee (FF) surcharge, which is levied by the California Public Utilities Commission on behalf of cities and counties in PG&E’s service territory for all customers. PG&E bundled customers pay the PCIA and FF fees associated with the most currently available vintage year. PG&E charges Pioneer customers the PCIA and FF fees based on the year that they transitioned to Pioneer service.

Visit pioneercommunityenergy.org for more information.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466. ©2025 Pioneer Community Energy. All rights reserved. “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation. ©2025 Pacific Gas and Electric Company. All rights reserved. 6.25 CCC-062025-5395 Electric Power
Generation Mix* Standard Green100***
Specific Purchases Percent of Total Retail Sales (MWh)
Renewable 22.9% 41.9% 100.0%
•Biomass & Biowaste**** 2.6% 2.9% 0.0%
•Geothermal 0.3% 4.0% 26.7%
•Eligible Hydroelectric 1.5% 4.7% 36.7%
•Solar Electric 14.1% 25.9% 0.0%
•Wind 4.4% 4.5% 36.7%
Coal 0.0% 0.0% 0.0%
Large Hydroelectric 12.5% 4.2% 0.0%
Natural Gas 1.9% 0.0% 0.0%
Nuclear 62.8% 0.0% 0.0%
Other 0.0% 0.0% 0.0%
Unspecified Sources of Power** 0.0% 53.8% 0.0%
TOTAL 100.0% 100.0% 100.0%
*As reported to the California Energy Commission’s Power Source Disclosure Program. Data is subject to an independent audit and verification that will not be completed until later in 2025. The figures above may not sum up to 100 percent due to rounding.
**Unspecified sources of power refers to electricity that is not traceable to a specific generating facility, such as electricity traded through open market transactions. Unspecified sources of power are typically a mix of all resource types, and may include renewables. ***Power mix is estimated for 2025, is subject to change, and will be verified with the 2025 PCL.
****3 percent of retail sales is covered by Unbundled RECs.

For information, visit:

Para detalles de este programa en español, visite:
參閱本計劃中文版本, 請上網:
pioneercommunityenergy.org
Pacific Gas and Electric Company
P.O. Box 997320
Sacramento, CA 95899-7320
We support your power to choose
As part of our mutual commitment to support your energy choice, Pioneer Community Energy (Pioneer) and Pacific Gas and Electric Company (PG&E) have partnered to provide you with a comparison of typical commercial electric rates, average monthly charges and generation portfolio contents.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466.
®
Plf)NEER

COMMUNITY ENERGY
Understanding your energy choice
2025 Commercial Electric Rate Comparison, B-1* Standard Green100 Generation Rate ($/kWh) $0.17244 $0.13444 $0.14532
PG&E Delivery Rate ($/kWh) $0.30264 $0.30264 $0.30264
PG&E PCIA/FF ($/kWh) -$0.02076 $0.01117 $0.01117
Total Electricity Cost ($/kWh) $0.45432 $0.44825 $0.45913 Average Monthly Bill ($) $483.83 $477.36 $488.95
*This compares electricity costs for an average small commercial customer in the Pioneer/PG&E service area (Placer County) with an average monthly usage of 1,065 kilowatt-hours (kWh). This is based on a representative 12-month billing history for all customers on B-1 rate schedules for PG&E’s and Pioneer’s published rates as of March 1, 2025.

Generation Rate is the cost of creating electricity to power your business. The generation rate varies based on your energy provider and the resources included in your energy provider’s generation supply.

PG&E Delivery Rate is a charge assessed by PG&E to deliver electricity to your business. The PG&E delivery rate depends on your electricity usage, but is charged equally to both Pioneer and PG&E customers.

PG&E PCIA/FF The Power Charge Indifference Adjustment (PCIA) is a charge to ensure that both PG&E customers and those who have left PG&E service to purchase electricity from other providers pay the above market costs for generation resources that were procured by PG&E on their behalf. “Above market” refers to expenditures for electric generation resources that cannot be fully recovered through sales of these resources at current market prices. PG&E acts as a collection agent for the Franchise Fee (FF) surcharge, which is levied by the California Public Utilities Commission on behalf of cities and counties in PG&E’s service territory for all customers. PG&E bundled customers pay the PCIA and FF fees associated with the most currently available vintage year. PG&E charges Pioneer customers the PCIA and FF fees based on the year that they transitioned to Pioneer service.

Visit pioneercommunityenergy.org for more information.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466. ©2025 Pioneer Community Energy. All rights reserved. “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation. ©2025 Pacific Gas and Electric Company. All rights reserved. 6.25 CCC-062025-5392 Electric Power
Generation Mix* Standard Green100***
Specific Purchases Percent of Total Retail Sales (MWh)
Renewable 22.9% 41.9% 100.0%
•Biomass & Biowaste**** 2.6% 2.9% 0.0%
•Geothermal 0.3% 4.0% 26.7%
•Eligible Hydroelectric 1.5% 4.7% 36.7%
•Solar Electric 14.1% 25.9% 0.0%
•Wind 4.4% 4.5% 36.7%
Coal 0.0% 0.0% 0.0%
Large Hydroelectric 12.5% 4.2% 0.0%
Natural Gas 1.9% 0.0% 0.0%
Nuclear 62.8% 0.0% 0.0%
Other 0.0% 0.0% 0.0%
Unspecified Sources of Power** 0.0% 53.8% 0.0%
TOTAL 100.0% 100.0% 100.0%
*As reported to the California Energy Commission’s Power Source Disclosure Program. Data is subject to an independent audit and verification that will not be completed until later in 2025. The figures above may not sum up to 100 percent due to rounding.
**Unspecified sources of power refers to electricity that is not traceable to a specific generating facility, such as electricity traded through open market transactions. Unspecified sources of power are typically a mix of all resource types, and may include renewables. ***Power mix is estimated for 2025, is subject to change, and will be verified with the 2025 PCL.
****3 percent of retail sales is covered by Unbundled RECs.

For information, visit:

Para detalles de este programa en español, visite:
參閱本計劃中文版本, 請上網:
pioneercommunityenergy.org
Pacific Gas and Electric Company
P.O. Box 997320
Sacramento, CA 95899-7320
We support your power to choose
As part of our mutual commitment to support your energy choice, Pioneer Community Energy (Pioneer) and Pacific Gas and Electric Company (PG&E) have partnered to provide you with a comparison of typical commercial electric rates, average monthly charges and generation portfolio contents.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466.
®
Plf)NEER

COMMUNITY ENERGY
Understanding your energy choice
2025 Commercial Electric Rate Comparison, B-1* Standard Green100 Generation Rate ($/kWh) $0.17187 $0.13390 $0.14478
PG&E Delivery Rate ($/kWh) $0.30277 $0.30277 $0.30277
PG&E PCIA/FF ($/kWh) -$0.02076 -$0.01682 -$0.01682
Total Electricity Cost ($/kWh) $0.45388 $0.41985 $0.43073 Average Monthly Bill ($) $452.27 $418.36 $429.20
*This compares electricity costs for an average small commercial customer in the Pioneer/PG&E service area (El Dorado County, Grass Valley and Nevada City) with an average monthly usage of 996 kilowatt-hours (kWh).

This is based on a representative 12-month billing history for all customers on B-1 rate schedules for PG&E’s and Pioneer’s published rates as of March 1, 2025.

Generation Rate is the cost of creating electricity to power your business. The generation rate varies based on your energy provider and the resources included in your energy provider’s generation supply.

PG&E Delivery Rate is a charge assessed by PG&E to deliver electricity to your business. The PG&E delivery rate depends on your electricity usage, but is charged equally to both Pioneer and PG&E customers.

PG&E PCIA/FF The Power Charge Indifference Adjustment (PCIA) is a charge to ensure that both PG&E customers and those who have left PG&E service to purchase electricity from other providers pay the above market costs for generation resources that were procured by PG&E on their behalf. “Above market” refers to expenditures for electric generation resources that cannot be fully recovered through sales of these resources at current market prices. PG&E acts as a collection agent for the Franchise Fee (FF) surcharge, which is levied by the California Public Utilities Commission on behalf of cities and counties in PG&E’s service territory for all customers. PG&E bundled customers pay the PCIA and FF fees associated with the most currently available vintage year. PG&E charges Pioneer customers the PCIA and FF fees based on the year that they transitioned to Pioneer service.

Visit pioneercommunityenergy.org for more information.

If this comparison does not address your specific rate, please visit PG&E online at pge.com/cca or call 1-866-743-0335. For information on Pioneer’s generation rates, please visit pioneercommunityenergy.org or call 1-844-937-7466. ©2025 Pioneer Community Energy. All rights reserved. “PG&E” refers to Pacific Gas and Electric Company, a subsidiary of PG&E Corporation. ©2025 Pacific Gas and Electric Company. All rights reserved. 6.25 CCC-062025-5396 Electric Power
Generation Mix* Standard Green100***
Specific Purchases Percent of Total Retail Sales (MWh)
Renewable 22.9% 41.9% 100.0%
•Biomass & Biowaste**** 2.6% 2.9% 0.0%
•Geothermal 0.3% 4.0% 26.7%
•Eligible Hydroelectric 1.5% 4.7% 36.7%
•Solar Electric 14.1% 25.9% 0.0%
•Wind 4.4% 4.5% 36.7%
Coal 0.0% 0.0% 0.0%
Large Hydroelectric 12.5% 4.2% 0.0%
Natural Gas 1.9% 0.0% 0.0%
Nuclear 62.8% 0.0% 0.0%
Other 0.0% 0.0% 0.0%
Unspecified Sources of Power** 0.0% 53.8% 0.0%
TOTAL 100.0% 100.0% 100.0%
*As reported to the California Energy Commission’s Power Source Disclosure Program. Data is subject to an independent audit and verification that will not be completed until later in 2025. The figures above may not sum up to 100 percent due to rounding.
**Unspecified sources of power refers to electricity that is not traceable to a specific generating facility, such as electricity traded through open market transactions. Unspecified sources of power are typically a mix of all resource types, and may include renewables. ***Power mix is estimated for 2025, is subject to change, and will be verified with the 2025 PCL.
****3 percent of retail sales is covered by Unbundled RECs.

For information, visit:

Para detalles de este programa en español, visite:
參閱本計劃中文版本, 請上網:
pioneercommunityenergy.org
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.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

See Demand.

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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

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