Pioneer Community Energy Board of Directors
June 19, 2025

Staff Report – Item 7
To: The Governing Board
From: Devin Reaves, Power Resources Manager
Item 7: Update on Power Markets and Energy Procurement
Date: 6/19/2025

RECOMMENDATION
Receive an update on power markets and energy procurement.

BACKGROUND
Energy Procurement accounts for over 90% of Pioneer Community Energy’s (Pioneer) operating costs and has been extremely volatile in the past couple of years. Staff have assembled this report in order to provide an update on the state of the power markets, to explain the reasons for the increased market volatility, and to provide updates on energy procurement including power purchase agreements (PPAs) for the expansion and some biomass projects.

In the 2021-2024 time period, increased demand for renewable energy credits (RECs) and resource adequacy (RA) in an already scarce California market due to legislative and regulatory requirements were primarily driven by California Senate Bills (SB) 350 and 100 (requiring minimum renewable energy purchases), and California Public Utilities Commission decisions on resource adequacy. SB 350 increased California's renewable electricity procurement goal from 33% by 2020 to 50% by 2030 with incremental increases on an annual basis and required that 65% of a load-serving entities’ (LSE) entire portfolio come from renewable resources on a compliance period basis.
• SB 350 formally defines three new Compliance Periods:
• Compliance Period 4: 2021-2024, four years
• Compliance Period 5: 2025-2027, three years
• Compliance Period 6: 2028-2030, three years
• SB 100 established a policy increasing renewable electricity procurement goal to 60% by 2030 and requiring renewable energy and zero-carbon resources supply 100 percent of electric retail sales to end-use customers by 2045.
• The California Public Utilities Commission (CPUC) requires all LSEs to procure their load share amount of resource adequacy on an annual basis.
• CPUC Decision 10-11-016 (Nov-2019) assigned an incremental 3,300 MW shared by all LSEs (18.5 MW for Pioneer)
• CPUC D.21-06-035 Mid-Term Reliability (MTR) (June 2021) assigned an incremental 11,500 MW (70 MW for Pioneer)
• Decision D.23-02-040 (February 2023) Updating and Adding to D.21-06-035 MTR Procurement Requirements assigned an incremental 4,000 MW (38 MW for Pioneer) • The CPUC has most recently developed reforms to its processes, including a “slice-of-day” resource adequacy program designed to ensure that load-serving entities procure sufficient resources to meet peak demand and charge system batteries after solar energy declines at the end of the day. Specifically, the CPUC’s 24-hour slice-of-day framework requires each load-serving entity to demonstrate enough capacity to satisfy its specific gross load profile — including a planning reserve margin — in all 24 hours on the ISO’s “worst day” of each month.

Plf)NEER

COMMUNITY ENERGY
Agenda Item: 7 Agenda Date: 6/19/2025

“Worst day” is defined as the day of the month that contains the hour with the highest peak load forecast. The SOD compliance requirement begins in 2025.

Since then, there has been a massive shift in pricing from 2024 and 2025 in the REC and RA markets. In 2024 Pioneer experienced all-time highs in both markets, with pricing at $90/MWh for a portfolio content category 1 (PCC1) bucket REC and calendar year 2024 (CAL 24) RA strip going for $30/kW-mo. A year later, today we are seeing 2022-23 level pricing with PCC1s at mid to low $20/MWh and CAL 26 RA strip at $10-$11/kW-mo.

Being compliant with legislative and regulatory requirements is very important to Pioneer, as it saves us tens of millions of dollars in avoided cost penalties. Even in these volatile market prices and scarce resource environment, Pioneer has managed to remain compliant in all categories. Pioneer has also made great progress on meeting its D.21-06-035 and D.23-02-040 requirements as will be further discussed below.

In addition to being compliant, pursuant to the Pioneer Board’s directive prioritizing investments in biomass energy, important progress has been made on the development of biomass projects in various stages.

Finally, Pioneer has spent a tremendous amount of time procuring and negotiating seven PPAs totaling over 1,500,000 MWhs and 500 MWs of RA (totaling approximately $2.5 billion in notional value) in preparation for the expansion into its 13 new communities.

ANALYSIS & DISCUSSION
Pioneer procures three types of energy products, namely California Independent System Operator (CAISO) Energy (Energy), RECs and RA. The following are updates on the respective markets.

Energy Markets
After another mild summer in 2024, forward Energy Prices have been on a decline. The reasons for the decline of CAISO Energy includes:
• Mild Weather Continuing
• Above average hydro production
• Battery penetration onto grid
• Cheap Natural Gas and Gas Storage surplus
The table below shows the year over year change of the forward curve for the time frame of June 2025 - May 2026, from snapshots taken between June 2024 – June 2025. The forward curve shows a decline in prices since the summer of 2024. The mild weather and strong supply stack, stated above, are the main drivers behind the decline in prices.
$-
$20.00
$40.00
$60.00
$80.00
$100.00
$120.00
$/MWh
CAISO Energy Prices (NP 15)
Jun-24 Sep-24 Dec-24 Mar-25 Jun-25 -
Agenda Item: 7 Agenda Date: 6/19/2025

Renewables Portfolio Standard (RPS) Market
The RPS market has fallen dramatically from the all-time highs Pioneer experienced last year. The current price quote for a PCC1 bucket REC is in the mid-low $20/MWh, whereas this time last year pricing was seen around $90/MWh. In the table below, pricing has come down to levels that were seen almost 3 years ago.

In last year’s report, Pioneer discussed that pricing could start seeing relief once project delays begin to resolve. That is what is happening now. With the continued buildout of California’s renewable energy stack no longer running into delays, the market has been flooded with RECs. This led to the large drop in pricing that is being seen now. The supply is outpacing the demand and unless there are changes legislatively/regulatory than the pricing will remain.

RA Market
The RA market has also experienced a large drop in pricing from last year. Like RECs, project delays beginning to resolve are bringing more RA into the market. Another big reason is there is more clarity on the Slice-of-Day (SOD) RA framework since it has been implemented. Pioneer suspects that any LSEs that may have had excess RA last year, held onto their length because there were still many unknows with SOD. Now that SOD has been around for a year LSEs feel more comfortable selling off any RA length, bringing more RA into the market.
$-
$10
$20
$30
$40
$50
$60
$70
$80
$90
$100
Jan 2023 May 2023 Sep 2024 June 2025
PCC1 Renewable Energy Prices ($/MWh)
$-
$20.00
$40.00
$60.00
$80.00
$100.00
$120.00
$140.00
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Resource Adequacy Prices ($/kW-mo)
Jan 2023 Oct 2023 June 2024 June 2025 -
Agenda Item: 7 Agenda Date: 6/19/2025

Forward pricing shows a slight upward trend in pricing. Where calendar year 2026 (CAL 26) is pricing $11/kW-mo and CAL 27 is at $17/kW-mo. This is mostly driven by the Year Ahead compliance deadline and is not reflective of how much RA is in the market.

Regulatory Compliance
Pioneer works hard to be compliant with all the Legislative and Regulatory requirements from agencies such as the CPUC and California Energy Commission. Pioneer has continued to stay in full compliance to save tens of millions of dollars in avoided cost penalties. Below is a list of the important compliance filings that Pioneer must complete:

Resource Adequacy
• Year Ahead Load Forecast
• Monthly Load Forecast Update
• Year Ahead Compliance Demonstration, System RA
• Year Ahead Compliance Demonstration, Flexible RA
• Historical load data, annual
• Monthly Compliance Demonstration, System and Flexible RA. • Year Ahead RA Plan
• Monthly RA Plan
• Annual Flexible Capacity Needs Assessment
• MIC Expansion Request
• New Use Import Commitment
• Local RA participation in Central Procurement Entity (CPE) showings/auctions • CAISO Maximum Import Capability Allocation Process
Renewables Portfolio Standards
• Annual RPS Compliance Report
• WREGIS REC Retirement Report
• Periodic Certificate Retirement (ongoing; not specific to a compliance program) • Compliance Report Verification
• RPS Procurement Plan data templates and select portions of narrative • WREGIS account management, certificate transfer review and retirement.

Power Source Disclosure Program
• Annual Report: Power Source Disclosure Program
• Annual Power Source Disclosure Report and Power Content Label Attestation • Annual Power Content Label
Quarterly Fuels and Energy Reports (QFER)
• CEC-1306B - Load Serving Entity (LSE) Quarterly Report US Energy Information Agency
• EIA 861M
o EIA 861
Integrated Energy Policy Report (IEPR)
• IEPR Demand Forecast (Biennial)
• IEPR Resource Plans (Biennial)
Integrated Resource Plan
• Load forecast comments and adjustments
• IRP data templates and select portions of plan narrative • D.19-11-016 and D.21-06-035 Mid-Term Reliability Procurement data template updates Joint Rate Comparison
• Joint Rate Comparison
• Joint Rate Comparison and Joint Rate Mailer
Agenda Item: 7 Agenda Date: 6/19/2025

PCIA Price Reporting
• PCIA Resource Adequacy Price Data Request
• PCIA RPS Price Data Request
Annual Emission Performance Standard Compliance Filing
• Contracts and compliance category for all contracts with terms of five years or longer Pioneer has recently submitted its IRP update for the Mid Term Reliability Decisions (D.21-06-035/D.23-02- 040) and is making great progress to meeting all of its requirements.

The table above shows Pioneer’s obligations for D.21-06-035 and D.23-02-040. The green cells show Pioneer has met their requirements and the yellow cells are open positions but are close to being filled. The requirement is that for each year Pioneer must procure the corresponding amount of MWs under a new build long-term power purchase agreement (PPA). Other than 2023, the online date or commercial operation date (COD) for the new build PPAs must be June 1st of each corresponding year (Example: Pioneer procured 19MWs in 2026 that had an online date of 6/1/2026 or before). Pioneer is in a great position to fulfill the rest of its requirements and is confident that it will continue to stay compliant.

Biomass Projects
Pioneer continues to work on developing biomass projects. Two projects that are under active development include one in Grass Valley with West Biofuels, and one at the Western Placer County Waste Management Authority with Wisewood Energy. Other projects that are in discussions or in the pipeline include projects in Anderson, Oroville, Mt. Lassen, and Georgetown (via Microgrid Incentive Program).

If all goes well, Pioneer expects the Grass Valley project to come online in 2026, helping to reduce fire-hazardous woody biomass from Grass Valley and the surrounding areas, providing much needed baseload renewable energy to the grid, and creating local jobs. The other projects are in varying stages of development.

Feed In Tariff
In November 2023, Pioneer’s Board approved a feed-in-tariff (FIT) specifically tailored towards local procurement of biomass and small hydroelectricity in its service territory. A few biomass projects have shown promise, but issues including sizing and pricing remain a constraint based on the current FIT parameters for projects to move forward.

To foster more engagement with the program an amendment was made to allow for RA-only contracts with standalone battery storage (BESS) contracts. Pioneer may need to add a full toll (energy and RA) contract price for BESS to allow more pricing options to developers.

Procurement for Expansion Communities
In order to meet the REC and RA compliance requirements as well as securing energy for its future customers, Pioneer has been actively negotiating PPAs totaling over 1,500,000 MWhs and 500 MWs of RA with 7 unique counterparties. Some PPAs have been executed, and all should be completed by the end of July. Approximately $2.5 billion in notional value will be considered for a prepay transaction to save tens of millions of dollars annually for Pioneer customers.

CPUC DECISION 2023 2024 2025 2026 2027 2028
D.21-06-035 MTR Requirement in NQC MWs 12 37 9 6 6
Diablo Canyon Replacement *included in the 37MW 15 8-Hour Battery Biomass D.23-02-040 Requirement in NQC MWs 19 19
Agenda Item: 7 Agenda Date: 6/19/2025

STRATEGIC PLAN
The recommendation supports the Operational Optimization goal.

FISCAL IMPACT
There is no direct fiscal impact with the recommendation, but power supply comprises over 90% of the operating budget.

ATTACHMENTS
There is no attachment to this report.

Staff Report – Item IV-B
To: The Governing Board
From: Donald Eckert Jr., Chief Executive Officer
Item IV-B: CEO Report
Date: 6/19/2025

PERSONNEL
Pioneer is excited to welcome our newest team member, Linda Praseudsuk, as our Senior Financial Analyst.

Linda has a background in accounting and earned her degree in Business Administration – Accountancy from CSU - Sacramento. Over the past few years, Linda had the opportunity to work with various public agencies as a consultant, where she specialized in governmental accounting and financial reporting.

Outside of work, Linda loves exploring new hobbies and trying new things. She dabbled in everything from paddleboarding and pottery to floral arrangement and reading. She also enjoys going to concerts, vintage shopping, and collecting perfumes. She finds a great deal of joy in creativity and self-expression.

Pioneer recently participated in job fairs at Sierra College and William Jessup University, promoting a summer internship program in the communications division. I am excited to announce Pioneer’s inaugural intern hiring of Brooke Sardella from William Jessup. Brooke is pursuing a degree in Business Management and will earn 4 units of credit through our 10-week internship. The internship is designed to provide hands on experience, exposure to the different applications of strategic communications, and provide support for social and digital graphics, as well as baseline research on the expansion communities.

There are currently no active recruitments.

CHIEF EXECUTIVE OFFICER AGREEMENTS EXECUTED (NON-POWER SUPPLY) There are no items to report.

EXPANSION UPDATE
Pioneer received Certification from the California Public Utilities Commission (“CPUC”) authorizing our expansion into thirteen (13) new communities with service beginning in October 2027 (see Attachment 5). Staff have reached out to the new communities for signature to the Pioneer’s Joint Powers Agreement which also is confirmation on their commitment and allows us to begin the power procurement process. As of June 13th, the following are communities that have confirmed:
• Cities of Chico, Oroville, Sonora and Willows
• Counties of Butte, Nevada, and Tuolumne
• Town of Paradise
Counties of Glenn and Sutter will be informing their Boards this month.

Cities of Live Oak, Orland, and Yuba City all have new City Managers in the past few months and expect confirmation by the end of June but must educate the new administrators on Pioneer.

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COMMUNITY ENERGY
Agenda Item: IV-B Agenda Date: 6/19/2025

NET ENERGY METERING (“NEMS”)
We are near the conclusion of our annual cash-out for NEM accounts that over-generated in the past year. This year’s numbers include:
• Approximately 9,000 customers have received cash-outs totaling $1.2 million. • More than 2,600 customers will receive bill credit due to their cash-out being less than $25.

AB706
AB706 – Forest Organic Residue, Energy, and Safety Transformation and Wildfire Prevention Fund Act continues to move along. It recently passed through the Assembly Floor with a 64-0 vote.

The bill ensures sustainable use of forest biomass waste in fire impacted communities without raising ratepayer costs.

EL DORADO COUNTY FAIR
Pioneer will have a booth as well as sponsor several events at this year’s El Dorado County Fair.

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. Meet and Greet with Supervisor Veerkamp from El Dorado County

3. Attended the Celebrity Waiters Lunch in Lincoln

4. Participated in annual operations check-up meeting with El Dorado Irrigation District

ATTACHMENTS

1. Agenda Planning Document

2. Legislative and Regulatory Report

3. Communications Report

4. Programs Report

5. Certification of Pioneer’s Implementation from the CPUC approving expansion Counterparty Name Execution
Date Type Product Start Date End Date Notional Value
Orange County Power Authority 5/2/2025 Buy Resource Adequacy - System 7/1/2025 9/30/2025 $635,560 Orange County Power Authority 5/2/2025 Sell Resource Adequacy - System 8/1/2025 9/30/2025 $170,830 Orange County Power Authority 5/2/2025 Sell Resource Adequacy - System 7/1/2025 9/30/2025 $223,340 Gaskell West Storage I LLC 5/22/2025 Buy Resource Adequacy - System 5/1/2026 2/29/2036 $32,497,200 Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 06-04-25

BOARD OF

DIRECTORS
JUNE 19, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: June 13)
JULY 17, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: July 11)
SEPTEMBER 18, 2025

REGULAR MEETING
3:00 PM
(Post Agenda: September 12)

IN THE FUTURE
Special Meeting
Closed Session
[time TBD]
Closed Session (EE Welfare & Benefits)

NO MEETING IN AUGUST
Next Meeting: SEPT 18, 2025
Regular Meeting
3:00 PM
Consent 1a Minutes for Approval-MAY 15, 2025 Minutes for Approval-June 19, 2025 Minutes for Approval-July 17, 2025 JULY RES Joint Rate Mailer (Stassi-Vanacore)
1b Receive Draft Financials: APR 2025
(Koehn)
Receive Draft Financials: MAY 2025
(Koehn)
RES Power Content Label
(Stassi-Vanacore)
Yes Energy (Kang)
1c RES Contract amendment-GreenLight
(Stassi-Vanacore)
RES Contract – Amperon (Kang) RES Compensation Adjustments & Employee Welfare & Benefits (Koehn)
1d RES Contract-Hall (Kang) RES amending Resolution 2021-1 re:

Long-term PPAs (Kang/GC)
1e RES Contract-PEA (Kang)
1f RES Contract amendment-cQuant
(Kang)
1g RES Contract – Maher (Koehn)
1h RES Contract amendment-CHW
(Koehn)
1i RES approving job descriptions (Koehn)
Presentation 2 presentation - CAISO Summer
Readiness (discussion-Eckert)
guest presenter-in person
presentation (Dr. Ahmad Faruqui)
guest presenter-in person
Power Charge Indifference Adjustment
(discussion-Eckert) guest presenter
RES Revised NEM Policy
(action-Koehn)
Regular 3 Power Supply Market Update
(discussion-Kang)
Outreach Plan for Expansion
Communities
(discussion- Stassi-Vanacore)
Update on advertising campaign
(discussion- Stassi-Vanacore)
Expansion update (Eckert)
4 RES Recommended Budget
(action-Koehn)
Receive Draft Financials: JULY 2025
(Koehn)
End of Legislative Session Update (Kang)
5 RES Update Cash Reserve Policy
(action-Koehn)
6 RES contract – printing services
(action- Stassi-Vanacore)
7 MicroGrid Incentive Program
(discussion-Kang)
JAN Annual Appointment of EPRC
Members (2026)
General Function II Chief Executive Officer’s Report
REG Reports:

Leg/Reg; Communications; Programs;
Introduction for new staff member;
JRM update; NEM cash-outs; Board
Workshop interest;
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
I I
I
I
Agenda Planning Document – Pioneer Community Energy ATTACHMENT 1 06-04-25

AUDIT/FINANCE COMMITTEE TO BE SCHEDULED - SEPTEMBER
in-person & remote locations IN THE FUTURE
David Ring, Chair
Richard Pearl, Vice Chair
Greg Janda
Gary Petersen

ENERGY PROCUREMENT REVIEW

AD HOC COMMITTEE

TO BE SCHEDULED
zoom only IN THE FUTURE
Gary Petersen, Chair
Alice Dowdin Calvillo, Vice Chair
Ryan Carter
Greg Janda
Sean Lomen
(JAN-BOARD) Annual Appointment of EPRC Members (2026)

EXPANSION

AD HOC COMMITTEE

TO BE SCHEDULED - JULY
zoom only IN THE FUTURE
Alice Dowdin Calvillo, Chair
Tom Ivy, Vice Chair
Suzanne Jones
Lori Parlin
o Potential Expansion opportunities
o prospective dates pending Governance Committee
scheduling
GOVERNANCE COMMITTEE TO BE SCHEDULED – JUNE/JULY
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 prospective dates; waiting for completion of the
Compensation Study

COMMUNITY ADVISORY COMMITTEE
TO THE CHIEF EXECUTIVE OFFICER JUNE 25, 2025 IN THE FUTURE Meets on the 4th Wednesday
(even-numbered months)

Attachment: Legislative and Regulatory Update
Date: 6/19/2025
Legislative Affairs
• On April 17, 2025, Pioneer Staff presented the 2025 Legislative Policy and Platform to the Board of Directors. Pioneer staff recommended and submitted letters of support for the following bills based on the Board’s approval:
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. • As of May 23, 2025, the deadline for fiscal committees to meet, below are the results for Pioneer’s high priority bills from their respective houses’ appropriations committees:
o AB 706 (Aguiar-Curry): Passed Assembly floor vote with minor amendments o AB 66 (Tangipa): Passed Assembly floor vote with no amendments o SB 88 (Caballero): Passed Senate floor vote with substantive amendments o SB 540 (Becker): Passed Senate floor vote with substantive amendments • CalCCA’s Legislative Committee and Executive Board voted to take positions on the following bills:
o “Support” position on AB 729 (Zbur): This bill would shift the time of year that the electric California Climate Credit is distributed to ratepayers, from its current schedule in the months of October and April to August and September of each year, when energy bills are typically at their highest.
o “Support position on AB 740 (Harabedian): This bill would promote virtual power plants by requiring the State Energy Resources Conservation and Development Commission, on or before November 1, 2026, to adopt a virtual power plant deployment plan. o “Neutral” on SB 842 (Stern) (Originally “Oppose unless amended” but has since been amended to remove the objectionable language): This bill would require the CPUC, on or before December 31, 2026, to produce a report identifying opportunities and needs to provide for local reliability with firm zero-carbon resources over the short-, mid-, and long-term, by including characterization of the resource attributes vital for local reliability and identification of barriers to deploying firm zero-carbon resources to enhance local reliability.

Plf)NEER

COMMUNITY ENERGY
2 [Publish Date] Agenda Date: 6/19/2025

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
[Publish Date] Agenda Date: 6/19/2025

R.21-03-011 OIR to Implement Provider of Last
Resort (POLR)
Limit the impacts of changes to the
Financial Security Requirement
(FSR)
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 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 day 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 [Publish Date] Agenda Date: 6/19/2025

program and 2) broadly review the program.
• May 1, 2024- CPUC approved the joint CCAs Tier 2 Advice Letter which approved the BioMAT standard 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.

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 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. [Publish Date] Agenda Date: 6/19/2025

• 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 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. 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.

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.

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.
• 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. [Publish Date] Agenda Date: 6/19/2025

• 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 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 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 [Publish Date] Agenda Date: 6/19/2025

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 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 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 [Publish Date] Agenda Date: 6/19/2025

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.

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. • 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. [Publish Date] Agenda Date: 6/19/2025

• 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 are dual enrollment prohibited. 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 proposed decision addressing AB 205 (Income Graduated Fixed Charge) requirements for electric utilities. The earliest this proposed decision 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. • 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. [Publish Date] Agenda Date: 6/19/2025

• 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 Proposed Decision 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 proposed decision 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. 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 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 [Publish Date] Agenda Date: 6/19/2025

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 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 [Publish Date] Agenda Date: 6/19/2025

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 Proposed Decision in PG&E’s 2022 ERRA Compliance proceeding that found that issues 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 Proposed Decision 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 Proposed Decision, providing support for CalCCA’s arguments in comments on that Proposed Decision. • 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 [Publish Date] Agenda Date: 6/19/2025

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.

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 proposed decision 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.
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.
[Publish Date] Agenda Date: 6/19/2025

• 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 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
[Publish Date] Agenda Date: 6/19/2025

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.

Utility Deenergization, 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 Deenergization 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.
[Publish Date] Agenda Date: 6/19/2025

• 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.

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-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. [Publish Date] Agenda Date: 6/19/2025

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-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 Proposed Decision on Track One of the PCIA rulemaking. If adopted by the Commission, the Proposed Decision 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 [Publish Date] Agenda Date: 6/19/2025

most controversial change regarded whether to include more historical transactions and, if so, from how far back. The Proposed Decision would include transactions up to four years prior. The Proposed Decision would also apply all of 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 Proposed Decision, CalCCA will oppose both the four-year historic transaction period and the application of the revised RA MPB to 2025 rates.
1 Attachment 3 Communications and Outreach Updates
Date: 6/19/2025
NOTABLE ACHIEVEMENTS – MAY 2025
• The May launch of our paid adverting campaign drove a massive increase in website traffic, marked by a 355% increase in activity, with more than 21,000 new users and 61,000 page views. • Year-to-year opt out rates represent a 48% reduction in opt-outs compared to 2024. • As part of our commitment to meeting customers where they are, Pioneer is using direct mail, e-blasts, flyers, paid advertising, earned media and in-person presentations to provide program information, answer customer questions, and increase brand awareness throughout our territory.

PAID ADS RAISE AWARENESS AND DRIVE WEBSITE TRAFFIC
Pioneer launched a paid advertising campaign focused on driving program participation and reaffirming our commitment to saving customers money. Ads are running in hyper-local media, digital and social media outlets. Our digital display ads are performing well, with an overall click-through-rate (CTR) of

1.19%. (This is significantly higher than the industry benchmark of 0.51%.) All ads drive visitors to our website, which has been further optimized to capture data for tracking visitor traffic and ad effectiveness. Google search and paid ads generated the most site traffic, with the top five web pages visited being:

1. PowerShift Rewards

2. AC Tune-Up Rebate

3. GridGen

4. Home Page

5. Residential Programs
The majority of website users in May were new. Website visitors are split on the devices they use when visiting the Pioneer website, with 57 percent using desktop, and 43 percent using Moville, and 10 Plf)NEER

COMMUNITY ENERGY
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percent using tablets. All page development and updates, now managed inhouse, take into account the different views to ensure a positive and effective user experience.

COMMUNITY OUTREACH
In-person outreach took place in a variety of forums and included:

Partners Helps Share Program Information
Pioneer’s community partners stepped up to help share information and promote programs, creating increased visibility throughout our service area. At least 1,500 flyers were distributed through:
• Public libraries in Placer and El Dorado Counties
• Retail locations carrying Pioneer’s discounted LED products • Community boards throughout our service area.

Additionally, our Auburn, El Dorado, Colfax, Grass Valley, Lincoln, Nevada City, Shingle Springs and Rocklin chamber partners distributed our program flyers via email to an estimated 30,000 recipients combined.

CUSTOMER CARE REPORTS AN UPTICK IN POSITIVE FEEDBACK
May was a busty month for customer care. Though the number of calls (391) was consistent with April, there was increased interest and questions about customer programs. • Most frequent topics were NEM (14.23%) and Billing Inquiry (12.51%) • Single busiest day was May 21 with 29 calls.
• 86 surveys were completed with a 93% satisfaction rate.

The chatbot had 597 interactions, a 24% increase from the previous month. Our e-blasts generated much of this activity, with May 27, the day we released information about GridGen’s CARE offering, being the busiest day with 11 conversations. Customer response to the chatbot remains positive, with a rating of 4.5/5 in satisfaction surveys.

Sponsorship and Engagement
• Lincoln Potters 2025 sponsorship
• Sponsorship of the Feeding the Foothills Event, El Dorado Hills • Sponsorship and attended Celebrity Waiters Lunch, Lincoln • Sponsorship of Mountain Counties Water Resources Association (MCWRA) Reception • Distributed FuSE information to 10 member agencies
• Emailed a status update to all 13 prospective members • Meeting with Auburn Chamber Executive Director
• Placer County Sociable Event
Community Meetings
• Provided public comment regarding Pioneer programs to all 10 member agencies • Presentation to Rocklin Chamber Sunrise Group
• Rocklin Chamber of Commerce Breakfast
• Loomis Chamber Government Relations Committee meeting • Lincoln Chamber Government Relations Committee meeting • Rocklin Chamber Government Relations Committee meeting • Rocklin Chamber Board of Directors Meeting (Pioneer represented on the Board) • State of the Town, Loomis

SOCIAL MEDIA
Top performing posts for May 2025:

Facebook
AC Tune-Up Rebate
LinkedIn
Savings Tip Tuesday
Instagram
PowerShift Rewards event on 5/30
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Attachment: 4 Program Updates
Date: 6/19/2025

AC Tune-Up (rebates for AC tune-up)
• The tune-up program relaunched April 1, 2025
• The current application count for the program season is 364. • A direct mail piece to all customers was delivered during the week of May 5. • An updated ad campaign to support the program launched in the week of May 12. • A program-focused newsletter was sent to all customers on May 8. • Pioneer’s quarterly newsletter, which featured programs including AC Tune-Up Rebate, was sent on June 5th.
• A program-specific postcard is scheduled to hit mailboxes in mid-June. • An increase in five star google reviews has been driven by customer support for the program, recognizing the efficiency of the customer care team.

GridGen (solar + storage)
• The expansion of the GridGen program to include battery retrofit, CARE/FERA offering, and commercial and industrial customers opened to customers the week of May 26. • Pioneer has generated a total of 235 leads, though not all leads follow through on system installation. o 41 customers in the active pipeline
o 11 have reached permission to operate
o 11 additional customers have signed contracts
• Pioneer staff is reaching out to customers who do not complete the process to gain insights and information for improvement in participation
• Pioneer is collecting customer testimonials to further leverage and promote the program. • GridGen was included in a program-focused newsletter that was sent to all customers on May 8. • A GridGen specific direct mail piece should be in mailboxes during the week of June 9. • The quarterly newsletter was delivered June 5th and highlighted programs, including GridGen and the new program offerings.

PowerShift Rewards (incentives for energy conservation) • PowerShift Rewards relaunched on May 1, 2025
• The program has over 1,100 customers enrolled.
• Pioneer has received CAISO certification as a Demand Response program. • This program was included in the direct mail piece to all customers with delivery during the week of May 5.
• The quarterly newsletter was delivered June 5th and highlighted programs, including PowerShift Rewards and the refer a friend offering.
• A PowerShift Rewards-specific postcard is planned for late June.

LED Discount (discounted LEDs at local hardware stores) • The LED Discount program has expanded to include Dollar Tree stores, making the total number of participating stores 26.
• This program remains very popular and provides visibility and community partnerships. o Retail partners are posting/distributing flyers about Pioneer’s other money-saving programs. • Given the popularity of this program, staff is recommending extending the program through 2025.

Online Marketplace (solar and/or battery storage purchasing) • Twenty-one (21) leads have been generated through the Electrum Marketplace.

Plf)NEER

COMMUNITY ENERGY
Agenda Item: x Agenda Date: 5/25/2023

Ice Energy Storage (ice technology used for AC energy reduction) • The Ice Energy team has started outreach to commercial customers:
o 196 site visits have been performed.
o 35 site surveys have been performed
o 9 sites have signed contracts with an estimated 61 ice bears to be installed. • Initial outreach focuses on Ice Energy's existing network of customers, but Pioneer has provided support as needed.
• This program has been promoted to all area Chambers of Commerce for visibility in the business community.
• The Ice Energy program was included in a programs-focused direct mailer that went to customers in May.
• Pioneer’s newsletter for commercial and industrial customers was delivered to commercial customers the week of May 8 and highlighted commercial programs such as Ice Energy.

Hourly Flex Pricing Pilot (credits for energy conservation for Ag customers) • The first Pioneer Ag customer has applied for participation in the program and is expected to move forward in the program.
• Due to concerns from CCAs, the Hourly Flex Pricing Pilot has re-opened for customer enrollments, however capacity on incentives may be reached soon and next steps are being discussed among PG&E and CCAs.

Community Advisory Committee
• The next Community Advisory Committee meeting will be held on June 25, 2025.

STATE OF CALIFORNIA Gavin Newsom, Governor

PUBLIC UTILITIES COMMISSION
505 VAN NESS AVENUE
SAN FRANCISCO, CA 94102-3298
June 9, 2025
Donald Eckert Jr., Chief Executive Officer
Pioneer Community Energy
2510 Warren Dr., Suite B,
Rocklin, CA 95677
[email protected]
RE: Letter Certifying Pioneer Community Energy’s Addendum No. 3 to the Community Choice Aggregation Implementation Plan and Statement of Intent Addressing Pioneer Expansion to the Cities of Chico, Live Oak, Orland, Oroville, Sonora, Willows, And Yuba City; The Town of Paradise; The Counties of Butte, Glenn, Nevada, Sutter, And Tuolumne Dear Donald Eckert Jr.:

I am writing to certify receipt of Pioneer Community Energy’s Addendum No. 3 to the Community Choice Aggregation Implementation Plan to expand to include the Cities of Chico, Live Oak, Orland, Oroville, Sonora, Yuba City, and Willows, the Town of Paradise and unincorporated Counties of Butte, Glenn, Nevada, Sutter, and Tuolumne. Addendum No. 3 to the Community Choice Aggregation Implementation Plan was submitted to the Energy Division on March 11, 2025, to begin service in these municipalities effective after October 1, 2027.

Pursuant to Public Utilities Code Section 366.2 (c)(7), within 90 days after the Community Choice Aggregator (CCA) establishing load aggregation files and submitting an Implementation Plan, the Commission is required to certify that it has received the Implementation Plan, including any additional information necessary to determine a cost-recovery mechanism.

Public Utilities Code Section 366.2 (c)(3) requires a CCA Implementation Plan to contain all of the following:

A) An organizational structure of the program, its operations, and its funding.

B) Ratesetting and other costs to participants.

C) Provisions for disclosure and due process in setting rates and allocating costs among participants.

D) The methods for entering and terminating agreements with other entities.

E) The rights and responsibilities of program participants, including, but not limited to, consumer protection procedures, credit issues, and shutoff procedures.

F) Details regarding the termination of the program.

G) A description of the third parties that will be supplying electricity under the program, including, but not limited to, information about financial, technical, and operational capabilities.

H) The methods for ensuring procurement from small, local, and diverse business enterprises in all categories, including but not limited to, renewable energy, energy storage system, and smart grid projects.

Pursuant to Public Utilities Code Section 366.2 (c)(4), a CCA is also to prepare and provide for all of the following:

A) A statement of intent; and
B) Provision(s) that provide for:

1. Universal access;

2. Reliability;

3. Equitable treatment of all classes of customers; and

4. Compliance with any legal requirements concerning aggregated service.

On June 29, 2023, in Decision (D.) 23-06-029, the CPUC adopted new requirements based on resource adequacy program compliance for load serving entities that elect to expand service (collectively, “RA LSE Expansion Requirements”). Because Pioneer Community Energy submitted Amendment No.7 to Pioneer’s JPA - Expansion following the effective date of the RA LSE Expansion Requirements, it is therefore subject to this new rule. Id. at 41.

Having found that Amendment No.7 to Pioneer’s JPA - Expansion complies with other applicable expansion requirements, CPUC staff evaluated the expansion effective date based solely on Pioneer Community Energy’s compliance with the RA LSE Expansion Requirements. Pursuant to this guidance, the CPUC reviewed Pioneer Community Energy’s RA filings. Energy Division staff have determined that Pioneer Community Energy is in compliance with the RA LSE Expansion Requirements and confirms October 1, 2027 as the effective date.

Energy Division staff confirms that Pioneer Community Energy’s Amendment No.7 to Pioneer’s JPA – Expansion contains the information required by Public Utilities Code Section 366.2 (c).

Should there be any modification to the Implementation Plan, including but not limited to the start date, anticipated load, and phase-in schedule, Pioneer Community Energy shall submit an updated Implementation Plan to the Commission in the same manner it submitted the original plan.

Pursuant to P.U. Code Section 366.2 (c)(7), the Commission is required to provide Pioneer Community Energy with “its findings regarding any cost recovery that must be paid by customers of the community choice aggregator to prevent a shifting of costs as provided for in P.U. Code Section 366.2 subdivisions (d), (e) and (f).” The costs referenced in P.U. Code Section 366.2 subdivisions (d), (e) and (f) are recovered via separate charges for: (1) Power Charge Indifference Adjustment (per kWh); (2) DWR Bond Charge (per kWh); and (3) Competition Transition Charge (CTC) (per kWh). By this letter, the Commission informs Pioneer Community Energy that these costs are identified on each of PG&E’s customer-class-specific tariff sheets, in the Electric Rates Schedules section.1
Sincerely,
Leuwam Tesfai
Deputy Executive Director for Energy and Climate Policy/ Director, Energy Division
California Public Utilities Commission
cc:

Scott Blaising ([email protected])
Gina Stassi-Vanacore ([email protected]) Jen-Ann Lee ([email protected])
Molly Sterkel ([email protected])
Christine Hammond ([email protected])
Aaron Jacobs-Smith ([email protected])
Dina Mackin ([email protected])
Mary Taylor ([email protected])
CCA Notices ([email protected])
1 PG&E Tariffs under Electric Rate Schedules: Schedule CCA-CRS 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.