notably, does not mention when/ where refinement of the Base Services Charge (BSC, formerly known as the IGFC) will occur. CalCCA had filed opening comments on the PD on August 14, 2025, recommending the CPUC keep the proceeding open to prevent prejudicing CCAs by not addressing items scoped into the proceeding, among other recommendations, which were ultimately not taken up. Thus, the board report will remove the Demand Flexibility proceeding from versions moving forward. • September 18, 2025- The CPUC adopted a new OIR on Demand Response, R.25-09-004, which presents a broader range of issues related to enhancing demand response in California, but is the most closely related proceeding to the topic of demand flexibility. Therefore, CalCCA will participate in the new Demand Response proceeding to carry on advocacy on these related issues, with the goals of ensuring CCA customers have equitable access to demand response resources and that new policies/ programs do not encroach upon CCA rate and program autonomy.
PG&E ERRA Compliance and ERRA Forecast:
• The ERRA proceedings act as a review of an IOU’s prior year portfolio management and accounting and seeks to identify errors and discrepancies between PG&E’s revenue requirements vis-à-vis collected revenues through the IOUs’ General Rate Case (GRC) which ultimately affects CCA rates through the Power Charge Indifference Adjustment (PCIA).
• May 14, 2023- PG&E’s 2023 – 2024 ERRA Forecast and Testimony was released. • June 1, 2023- NewGen sent over the new rate forecast spreadsheet. The forecast looks good with the PCIA remaining negative over many vintages, but this will change before the October Update. • June 16, 2023- Keyes and Fox filed a Protest to PG&E's Forecast Application. • August 10, 2023- CalCCA filed a Protest to PG&E’s ERRA Trigger Application proposing a rate increase in November to correct and account for under-collections.
• September 6, 2023- CalCCA provided Testimony on the 2024 PG&E ERRA Forecast case and touched upon the fixed generation cost issue.
• October 16, 2023- PG&E’s October Update to its 2024 ERRA Forecast came out. Energy prices have softened relative to PG&E’s original forecast (which would, all else equal, cause PCIA rates to increase), but RA and RPS benchmarks have increased significantly since PG&E's filing (dampening the impact of energy prices).
All told, forecast rates increased relative to the original forecast across the board, but forecast rates remain negative for vintages 2021 and later.
• November 1, 2023- Keyes and Fox submitted comments on PG&E’s ERRA Trigger proposal and comments on PG&E’s October update.
• November 16, 2023- The CPUC unanimously approved the Alternate PD and indicated that “the decision balances a myriad of competing interests- affordability, feasibility, safety, and reliability.” PG&E requested $15.4 billion for 2023, and the decision reduced that amount by $1.8 billion to $13.5 billion. This is an 11% increase from the authorized 2022 revenue requirement. For the typical residential customer, their combined monthly electric and natural gas bill will increase by $32.62 or 12.8%, compared to PG&E’s request of $38.73 or 17.9% increase.
• November 30, 2023- The PD for the PG&E 2024 ERRA Forecast came out. There were a couple of disputed issues including whether to amortize the 2023 trigger balance over 6 months or 12. CalCCA was asking for 12 and PG&E was asking for 6 months. The CPUC adopted PG&E’s recommendation. The second issue was whether PG&E should apply a first-in-first-out methodology to the use of excess prior year RECs or a last-in-first-out methodology. The CPUC ruled with PG&E on a last-in-first-out methodology. • December 12, 2023- A revision to the PD came out and CalCCA won its argument on first-in-first-out, meaning the CPUC is requiring PG&E to use a first-in-first-out methodology for RECs banked in or after 2019.
• December 29, 2023- PG&E submitted their Annual True-Up to change PG&E’s electric rates on January 1, 2024.
• March 21, 2024- There was a Preliminary Issue Review with Keyes and Fox. The 2021 ERRA proceeding is still open but coming to an end, 2022 is still busy, and 2023 is just starting up. Some of the big issues to watch include PG&E’s RA Sales and Accounting; DWR reimbursement to PG&E; and Retained, Sold and Unsold RPS.
[Publish Date] Agenda Date: 10/16/2025
• 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 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 [Publish Date] Agenda Date: 10/16/2025
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 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, [Publish Date] Agenda Date: 10/16/2025
including preliminary issues it identified concerning PG&E’s RA sales activities, PG&E contract amendments, changes to PG&E’s Retained RA Tracker, and PG&E’s treatment of “banked” renewable energy credits to meet its Renewable Portfolio Standard (RPS) requirement. CalCCA also argues that the Commission should explicitly include PG&E’s attempts to sell excess RA consistent with its Bundled Procurement Plan in 2024 within the scope of the proceeding.
• April 23, 2025 – The ALJ issued a PD in PG&E’s 2022 ERRA Compliance proceeding that found that issues concerning PG&E's sales or attempts to sell excess RA during the summer of 2022 are not relevant to issues in the proceeding. CalCCA will file comments on the PD pushing back on this finding given that the ERRA Compliance proceedings are the only venue we have to examine PG&E’s excess RA transactions. • May 2, 2025 – The ALJ in PG&E’s 2024 ERRA Compliance proceeding issued a scoping ruling that included CalCCA's request to include as an issue whether PG&E made reasonable attempts to sell excess RA consistent with its Bundled Procurement Plan. This Scoping Ruling conflicts with the 2022 ERRA Compliance PD, providing support for CalCCA’s arguments in comments on that PD. • May 15, 2025 – PG&E filed its 2026 ERRA Forecast application, which will, in part, establish the PCIA rate for 2026.
• June 11, 2025 – Keyes & Fox and NewGen convened a preliminary issue review regarding the PG&E 2026 ERRA Forecast application. From NewGen’s preliminary analysis, it is apparent that there will be a significant under-collection for Portfolio Allocation Balancing Account, which will have to be recovered through the 2026 PCIA, putting upward pressure on that rate. There are other issues that Keyes & Fox will litigate to potentially help ease the PCIA rate increase in 2026 (e.g., battery RA valuation, use of banked RECs, PG&E’s GHG free sales, etc.), but even if successful, that increase is expected to be significant. • June 18, 2025 – CalCCA filed a protest of PG&E’s 2026 ERRA forecast. The protest highlighted the issues discussed in the June 11, 2025 preliminary issues review regarding PG&E valuation of both pre-2019 banked RECs and the RA attributable to batteries in its PCIA portfolio. PG&E effectively values both at zero, which has the effect of increasing the PCIA.
• September 2, 2025 – CalCCA filed testimony in PG&E’s 2026 ERRA Forecast proceeding. The testimony went into detail on the two issues identified in CalCCA’s protest on pre-2019 banked RECs and valuing the RA attributes of battery storage, arguing that PG&E’s approach does not properly compensate unbundled customers for the value of resources procured on their behalf. • September 15, 2025- CalCCA filed intervenor testimony in PG&E’s 2024 ERRA Compliance case, proposing that PG&E file Supplemental Testimony to correct the amount of Retained and Unsold RA and the associated credit to their Portfolio Allocation Balancing Account (PABA). PG&E’s bundled procurement plan (BPP) establishes that RA held from the market for Operational Constraints should be valued as Retained RA.
However, CalCCA found that some of this RA was valued as Unsold RA, which gets valued at zero, leading to a lower credit to the PABA and an increase to the PCIA. CalCCA proposes PG&E file Supplemental Testimony to correct this error and to credit the PABA associated with valuing the RA withheld for Operational Constraints as Retained RA.
• October 1, 2025- The CPUC released the 2025 MPB values for the PCIA Forecast and True-Up, which will be used by the IOUs in their 2026 ERRA Forecast Updates set to be released October 15, 2025. The 2025 MPB calculations incorporate the changes that were made to the RA MPB methodology in the PCIA Track 1 decision. For RA, 2025 System Forecast was $42.54/kW-mo., 2025 Actual is $11.21, and 2026 Forecast is $11.53. The steep decline of the 2025 actual versus 2025 forecast value will create substantial upward pressure on the PCIA adder for unbundled customers. For RPS, 2025 System Forecast was $71.24/MWh, 2025 Actual is $63.86, and 2026 Forecast is $62.45. For 2026 Forecast Energy Index: PG&E on peak is $50.20/MWh and off peak is $52.31/Mwh. The 2025 Forecast indices for PG&E were on peak of $55.02/MWh and off peak of $53.18/MWh.
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), [Publish Date] Agenda Date: 10/16/2025
re-entry fees, and LSE de-registration process and compliance requirements. • July 31, 2023- CalCCA's Reply Briefs were submitted and address PG&E’s proposal to modify the FSR to reflect two months of forecast energy costs, other parties’ recommendations on elements of the existing FSR calculation, mandatory contract assignments, financial monitoring, and the duration of POLR service. • March 14, 2024- The CPUC issued a PD, with a mix of favorable and unfavorable decisions. For example, it rejected PG&E’s proposal to require FSR postings to reflect 2 months of POLR service, it maintains the ability to use service bonds, and it keeps confidential the information about LSEs that trigger financial monitoring.
However, the PD also approved using PG&E’s Administrative Fee ($4.24) without sufficient evidence of the costs, the CPUC should clarify that November 2024 FSR Calculation would be the earliest possible calculation under the new rules, and the CPUC should clarify the timing of the second tier of reporting requirements so CCAs know when to evaluate their metrics. The biggest issue the PD addressed was updating the FSR requirements. The minimum FSR remains $147,000, but now CCAs must use the IOU’s Administrative Fee multiplied by the number of accounts the CCA has, and post whichever amount is higher. For CCAs in PG&E’s territory the administrative fee is $4.24 per customer, while the other IOUs’ administrative fees are significantly less (around $.50 per customer). If the final decision requires CCAs within PG&E’s service territory to use PG&E’s administrative fee, all CCAs within PG&E’s service territory will likely be paying an FSR well over the $147,000 minimum.
• April 23, 2024- CPUC adopted a revised POLR Decision inclusive of several of CalCCA’s requests.
Specifically:
o Reducing RA costs in the FSR by accounting for returning CPE RA allocations, in addition to the CAM and DR RA allocations.
o Nets PCIA in the FSR whether the PCIA is positive or negative. o Affirms current timing for calculating FSRs.
o Provides CCAs with an additional 60 days to file first FSR following IOU tariffs implementing this decision.
o Requires CCAs to file the Tier 1 audited financial report to Energy Division once a year, in January or July, whichever comes earlier relative to the availability of the audited financial statement.
o Allows 90 days for CCAs to submit joint advice letter on new CCA registration process • July 12, 2024- CalCCA, on behalf of Pioneer, filed a Tier 2 AL to formalize the Financial Monitoring and Reporting Guidance document. The CPUC requires financial reporting to be done on a 2-tier system. Tier 1 requires every CCA to submit an annual audited financial report. Tier 2 requires CCAs to submit additional financial reporting, if certain trigger events such as a change in credit rating occur. This document clarifies the process and procedures CCAs must follow to comply with Tier 2 financial reporting conditions. o July 22, 2024- The joint IOUs filed a protest to the joint CCAs’ AL on Financial Monitoring and Reporting Guidance, insisting CCAs’ use “lines of credit” instead of “letters of credit” as the primary financial instrument to demonstrate days of liquidity of hand (DLOH). The IOUs also insisted CCAs report financial triggers 10 days after they occur, instead of the proposed 60 days.
o September 6, 2024- CalCCA met with Energy Division to express that CCAs agree to comply with the joint IOUs’ request to use “lines of credit” to calculate DLOH. On the issue of minimum days required to report financial trigger events, CCAs insist on keeping 60 days, as this is the minimum amount of time required to prepare accurate financial statements due to complex billing and accounting systems.
• July 17, 2024- CalCCA, on behalf of Pioneer, filed a Tier 2 AL to clarify requirements for the new CCA registration process and implementation plan. These requirements include (1) submission of a feasibility study and pro forma financial statement with the Implementation Plan, (2) establishment of annual assumptions to be included in the pro forma financial statement, (3) establishment of milestones for critical implementation action and review progress, and (4) submission of an updated proforma financial statement six months prior to launch. The AL served to provide additional examples for annual assumptions and critical milestones.
[Publish Date] Agenda Date: 10/16/2025
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
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
[Publish Date] Agenda Date: 10/16/2025
• May 12, 2025- PG&E sent Pioneer our FSR calculation worksheet and advice letter. The materials indicate Pioneer must post the new FSR minimum of the per-customer admin fee. Pioneer has posted our balance to reflect our new FSR minimum.
• May 28, 2025- An ALJ issued a ruling proposing a procedural pathway for Phase 2. Due to lack of interest from non-IOU entities in assuming the POLR role, as indicated in the Phase 2 opening comments, the ALJ ruling proposes for the CPUC to issue a decision providing a framework for its regulatory authority over a non-IOU POLR and the services it provides. That decision would then close the current proceeding, and direct any non-IOU entity seeking POLR status to file a Petition for Rulemaking at least 12 months before filing an application to assume POLR responsibilities. The Commission would then resume consideration of threshold questions and topic areas set forth in the Scoping Memo. The ALJ ruling also seeks comments on proposed definitions regarding “POLR services”, to inform the framework around CPUC regulatory authority over a non-IOU POLR entity.
• June 13, 2025- CalCCA filed opening comments on the ALJ ruling, supporting the proposed procedural pathway for Phase 2. As for the proposed definitions regarding “POLR services”, CalCCA clarifies that the Commission need only to adopt a definition for “POLR-specific services”, because defining “Full-severable services” or “Non-severable services” is unnecessary as they are not within the Commission’s jurisdiction according to existing regulation and statute. CalCCA emphasizes that any POLR framework must preserve the protected autonomy of non-IOU LSEs by limiting the CPUC’s jurisdiction to POLR-specific services. • June 20, 2025- CalCCA filed reply comments on the ALJ ruling, responding to opening comments from parties including Cal Advocates, PG&E, SDG&E, and SCE, which try to unreasonably assert broader CPUC jurisdiction over non-IOU LSE POLRs.
Utility De-energization, PSPS, and EPSS:
• July 12, 2022-Pioneer, along with Joint CCAs, Joint Local Governments, and Rural County Representatives of California (RCRC), filed a motion with the CPUC on July 12, 2022, to consider EPSS issues in the De-energization or its own Proceeding. The arguments in the motion seek to treat EPSS events with the same regulations and oversight as Public Safety Power Shutoff (PSPS) events. • September 21, 2023- The CPUC approved a PSPS citation program for violations of the established PSPS guidelines.
• August 30-31, 2023- PG&E provided a post PSPS report. A total of 3,928 customers were deenergized. • October 10, 2023- The Joint CCAs, RCRC, and Joint Local Governments had a meeting with the Public Advocates Office to see if there is agreement on the need to further do more with regards to Fast Trips. The Public Advocates Office indicated that the CPUC and Office of Energy Infrastructure Safety are not inclined to act to regulate Fast Trips and that more data is needed. The Public Advocates Office is looking to submit a report in the beginning of 2024.
• January 16, 2024- The data for December’s Fast Trips and YTD data came out. These are the following circuits in Pioneer’s territory with 8 or more outages in 2023:
o Placerville 2106 (EDC)- 19
o Apple Hill 2102 (EDC)- 18
o Shingle Springs 2109 (EDC)- 11
o Mountain Quarries 2101 (EDC)- 11
o El Dorado PH 2101 (EDC)- 11
o Clarksville 2104 (EDC)- 9
o Apple Hill 2104 (EDC)- 9
o Lincoln 1101 (Placer)- 8
o Penryn 1103 (Placer)- 8
o Penryn 1107 (Placer)- 8
o Brunswick 1105 (Nevada)- 17
o Brunswick 1106 (Nevada)- 15
• January 29, 2024- A data request was made by joint CCAs (including Pioneer) using the circuits listed above to PG&E requesting the number of customers served by each circuit, the number of life support customers, the number of medical baseline customers, and the number of critical facilities served by each circuit. [Publish Date] Agenda Date: 10/16/2025
• March 8, 2024- Part of the information we were seeking regarding the data request came back. Pioneer staff will be reviewing this information.
• August 23, 2024- PG&E completed our data request made in January, except for information regarding hardening projects on the circuit including their pole numbers, project location and timeline, and type of hardening work to be completed, on the grounds these questions are out of scope and are unduly burdensome. Pioneer staff will be reviewing the rest of the data request provided. • May 8, 2025 – The CPUC will host a workshop regarding outage data collection, specifically focusing on data definitions and reporting.
• August 22, 2025 - Commissioner Baker and the Administrative Law Judge issued a ruling revising the scoping memo and schedule for Track 1 (outage reporting) of the safety and reliability proceeding. As it currently stands, the parties have submitted comments on the utilities’ current outage reporting and changes they would like to see, and the CPUC held a workshop during which our coalition presented our recommendations. The original plan for CPUC staff to issue a staff proposal for a revised set of reporting requirements, which would then be the subject of another workshop and opening/reply comments. The new plan is for the large utilities to submit a joint draft customer reliability report template by October 31, after which parties can file opening and reply comments on the proposal by November 14 and December 3, respectively.
CEC Load Management Standards (LMS):
• October 12, 2022- The CEC adopted the Load Management Standards regulation which requires the development of a statewide standard tool for authorized rate data access by third parties that is compatible with each IOU, large POUs, and large CCAs with the idea that electricity customers or their authorized third-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- [Publish Date] Agenda Date: 10/16/2025
biased review process based on economic and technological feasibility. Commissioner McCallister stated his intentions to work with his LMS staff to expedite CCAs’ LMS Compliance plans for approvals through increased flexibility.
• March 5, 2025- Pioneer corresponded with CEC LMS staff regarding program development in our LMS Compliance Plan. We provided an update that our LMS programs are not currently set up to connect price signals to the CEC’s MIDAS system, which is currently not functioning well per an operations update from our vendor who handles MIDAS interactions, Calpine. Pioneer will continue to monitor the situation to see if it is technologically and financially feasible to add this component of MIDAS price signals to our LMS programs in the future, when the MIDAS system issues are resolved. • May 8, 2025- The CEC, in a business meeting, will vote to delay the SST submission until May 8, 2026. • June 19, 2025- The CEC issued a formal revision request letter to Pioneer regarding our LMS Compliance Plan, which we are directed to revise to, in part, commit to offer the hourly flexible rate pilot programs of PG&E. The CEC directs us to file our board-approved revised plans by September 17, 2025 or 1 week following board approval of the revised plan.
• September 19, 2025- Following Board approval at the September Board meeting, Pioneer submitted its revised LMS Compliance Plan, with the language additions requested by the CEC, to the CEC LMS docket.
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 [Publish Date] Agenda Date: 10/16/2025
arguing that application of any changes to the RA MPB to true-up 2025 rates is not allowed under the prohibition against retroactive ratemaking and that any decision must be supported by substantial evidence and narrowly tailored to the supposed transaction volume problem. The IOUs also filed testimony with substantive arguments supporting their position that the CPUC should look at historic RA transactions when determining the RA MPB.
• April 23, 2025 - CalCCA filed an opposition to the IOUs' motion to admit testimony, arguing that such testimony is inconsistent with the procedures established by the Administrative Law Judge and prejudices other parties.
• April 30, 2025 - Parties filed reply briefs primarily focusing on the legal arguments and the issue of whether to include historic RA transactions in the calculation of the RA MPB. CalCCA also filed its own testimony in response to the IOUs'. This may create a procedural and due process problem for the CPUC that could possibly delay a decision.
• May 23, 2025 – The Administrative Law Judge issued a PD on Track One of the PCIA rulemaking. If adopted by the Commission, the PD would make a variety of changes to the RA MPB methodology intended to make the result of that calculation more representative of RA value. Many of the changes were generally agreed upon by parties, including eliminating non-market transactions and combining the three different RA products (local, flex, and system) into a single RA MPB calculation. The most controversial change regarded whether to include more historical transactions and, if so, from how far back. The PD would include transactions up to four years prior. The PD would also apply all these changes to true-up currently effective 2025 rates, which will create a significant under-recovery that will have to be collected in 2026 rates, increasing the PCIA. In comments on the PD, CalCCA will oppose both the four-year historic transaction period and the application of the revised RA MPB to 2025 rates. • June 27, 2025 – The CPUC issued a Final Decision adopting the PD on Track 1 of the PCIA rulemaking. As described above, the effect of the decision will decrease the value of the IOU’s generation resources in rates effective in 2025, which will increase the 2025 PCIA under-collection. That under-collection will need to be recovered in the 2026 PCIA rates, increasing that rate for Pioneer’s customers. • July 28, 2025 – CalCCA filed an application for rehearing of the Track 1 Final Decision, requesting that the CPUC reconsider its decision to apply the revised RA MPB to 2025 PCIA rates. CalCCA argues that the CPUC’s Final Decision commits legal error because application of the RA MPB to 2025 PCIA rates violates the prohibition against retroactive ratemaking.
1 Attachment 3: Communications, Outreach & Customer Care Updates Date: 10/16/2025
PIONEER ACHIEVES 4-STAR GOOGLE REVIEWS
With dozens of positive reviews about customer service and programs, Pioneer now exceeds all other CCAs in the quantity and overall score for Google reviews. This favorable score is important for reputation-building, as this is often the first thing people see if they search Pioneer online.
WEBSITE
More than a quarter of our website traffic in September was driven by paid ads. However, organic search and direct leads also brought traffic to the site. Direct traffic -- traffic that comes to the site without first visiting another site - is significant because it also represents brand recognition.
Top pages viewed:
1. AC Tune-Up Rebate
2. Home Page
3. GridGen
4. PowerShift Rewards
5. Career Opportunities
Spikes in activity correspond with the release of a direct mail piece promoting programs that dropped during the second week of September.
OUTREACH & COMMUNITY PARTERSHIP
Staff had a busy and productive month with an on-site presence at more than a dozen events, high profile event sponsorships, and presentations at expansion-related meetings. Specific activities include:
Local Presence
• Rocklin Chamber Sunrise Meeting and Board of Directors Meeting • Loomis Chamber Meeting
• Lincoln Government Relations Committee Meeting
• Regional Economic Development Stakeholders Meeting
• Joint Economic Development and Government Relations Meeting • PG&E Third Quarter Meeting Working Group – North Valley and Sierra Sponsorships
• Rural Counties Representatives of California - Annual conference sponsor • League of California Cities – Regional lunch sponsor
• Leadership Rocklin Lunch sponsor and presentation
Plf)NEER
COMMUNITY ENERGY
4.0 *** 120 reviews CD ***** a day ago NEW
We are benefiting from staying with Pioneer!
All rebate 36 program 12 HVAC 12 bill 8 +6
• Hot Chili, Cool Cars event sponsor
• Patriots Day event sponsor
• Latino Leadership Conference - Sponsorship and event presence • Auburn Chamber Celebrate the Community Event Sponsor
Programs Support
• Memorandums of Understanding signed with City of Rocklin and Nevada City • Meetings set next month with Placer County and Placerville Expansion
• Informational briefings to staff of Madera County, City of Chowchilla and City of Madera • Informational briefing with Colusa County Assistant Chief Administrative Officer • Presentation to Madera County Supervisors
• Presentation to Chowchilla City Councils
CUSTOMER CARE
Our customer care team continues to get consistently high scores for customer satisfaction, with a
93.2% satisfaction rate in 146 surveys.
Our team fielded a total of 622 calls in September (down 5% from August). Interest in rebates was the most frequent topic at 14.85%, and Billing Inquiry was the second most frequent at 11.78%.
Our chatbot continues to perform well and take pressure off the call center with :
• 612 interactions
• 142 live conversations (3% decrease from August)
• 6 re-enrollments in September
• 5/5 average satisfaction rating
SOCIAL MEDIA
Top performing posts in September centered on Pioneer’s community involvement. Facebook following now exceeds 900.
LinkedIn:
Placerville Community Pool Energy
Efficient Equipment Upgrade
Sponsorship
Facebook:
National A/C Tune-Up Day
Instagram:
Rocklin’s Hot Chili and Cool Cars
event
Ct). :!~~:~:~~~~ ~!~ ~
Pioneer proudly received a certificate of appreciation from the City of Placerville for our sponsorship of their energy-efficient City pool repairs. We are proud and honored to support the communities we serve, and we strive to make them better each day with contributions big and small. Thank you, Placerville.
PIONEER COMMUNITY ENERGY
Certificate ~!:;.f?.Preciation
'Pioneer Community 'Ineray
THANK YOU,
CITY OF PLACERVILLE
t ) =~cw;:ua::: ~ nN>ff2l.t2l43PM 0
Celebrate NatlONI Tune-Up Day this week and t.ike .advantage ofthe last few days of our AC.
Tu~-Up RN>at~ P"Ogl"am! Rrc~ a tu~-up by Odober 1 .-.cl submit your apPlication by Odober 15 to get up to S75 back from Pioneef. Learn more on our website. ....,, _ _,,....,fflllfl""ll_ ,.,,.,'l"ITIUlll"IIIII
PIC)NEER
COMMUNITY ENERGY
We are honored to sponsor the 2025
Rocklin Hot Chili and Cool Cars event
September 20th!
PAID CAMPAIGN
The paid campaign concluded at the end of September. Overall, the campaign delivered 5.7 million impressions from May through September, resulting in more than 41,500 clicks to our website and nearly 5,400 conversions (filling out a form after clicking the ad). Below summarizes campaign efforts for September.
Tactic Program Delivered
Impressions Clicks Click Thru Rate
Digital Display
AC Tune Up 386,827 1,704 0.44%
GridGen 114,570 1,000 0.87%
PowerShift Rewards 112,278 676 0.60%
Local Sites Display
AC Tune Up 210,438 541 0.26%
GridGen 204,497 617 0.30%
PowerShift Rewards 59,909 147 0.25%
Mobile Ad Messenge
AC Tune Up 70,237 1,526 2.17%
GridGen 70,282 1,534 2.18%
PowerShift Rewards 43,790 963 2.20%
Paid Search
AC Tune Up 1,179 204 17.30%
GridGen 2,215 242 10.93%
PowerShift Rewards 5,795 314 5.42%
NextDoor
AC Tune Up 15,884 60 0.38%
GridGen 15,902 17 0.11%
PowerShift Rewards 16,173 25 0.15%
Paid Social
AC Tune Up 109,920 799 0.73%
GridGen 169,990 969 0.57%
PowerShift Rewards 99,323 686 0.69%
Total 1,709,209 12,024 0.70%
Attachment 4: Program Updates
Date: 10/16/2025
• 1,933 applications received to date.
• Application period closed October 1, but customers have until October 15 to submit invoices. • El Dorado (458), Lincoln (377), and Rocklin (368) customers have the largest number of program participants.
• 216 contractors are participating in program.
• Pioneer staff are proactively engaging the program partner to strategize improvements for next season and potential ways to make the program even more advantageous for Pioneer customers. • Second most popular Pioneer webpage customers visit.
• Updated application process with online submission option is a primary driver in Pioneer currently receiving four-star Google review scoring, highest amongst all CCAs. • 1,769 enrolled customers.
• Season runs through October 31, though enrollment is available year-round. • Seven events called during 2025 season to date.
• Energy reduction: More than 1.9 mWh
• Load shed: more than 625 kW
o Energy reduction and load shed numbers are nearly double 2024, despite an unexpectedly mild summer compared to historical norms.
• Supported by direct mail, newsletter/email campaigns, paid and earned social media. • This is the most popular Pioneer webpage for customers to visit. • The GridGen program continues to gain momentum, especially amongst local contractors looking to utilize the program’s unique financial benefits. These local contractors are actively marketing the program which now includes battery retrofit, CARE/FERA offering, and commercial and industrial (C&I) customers
• 17 projects completed with final inspection received. • 14 customers achieved permission to operate.
o 147.5 KW solar capacity installed
o 84,813.50 kWh of energy generated
• Staff continue proactively reaching out to customers that did not complete the program application to determine if there is an opportunity to re-engage.
• Customer testimonials to support marketing efforts are being gathered. • Contractor marketing materials approved by Pioneer staff-local contractors continue to be an effective marketing tool.
• Staff continue working closely with partners to ensure product offering is accessible, beneficial and a value-add for Pioneer customers.
Plf)NEER
COMMUNITY ENERGY
a\ AC TUNE-UP
\.V REBATE
a\ POWERSHIFT
\.V REWARDS
@ GRIDGEN
Agenda Item: 1a Agenda Date: 9/18/2025
Ice Energy Storage (ice technology used for AC energy reduction) • 25 Participation Agreements under review.
o ~200 units would be installed
• Ice Energy team has conducted:
o More than 200 site visits
o 36 site surveys
o 125+ Active leads
• Marketing efforts continue, promoting at all area Chambers of Commerce, direct mailers and in Pioneer’s newsletters.
• Placer County and City of Rocklin are in discussions about potential projects.
Clean Fleet Revenue Program
• Program is active with outreach continuing to member agencies. • Staff will meet with Placer County on October 15 to discuss the program in more detail, and Placerville will be scheduled this month.
• Staff met and/or connected with Cities of Rocklin, Nevada City, Auburn, Lincoln, Placerville, Loomis and both counties.
• Rocklin and Nevada City approved resolutions to participate in program, and Auburn is also considering participation.
• Per Board approval at the September 18, 2025, meeting allowing Pioneer to extend participation in cost neutral programs, staff will now begin to strategize the appropriate outreach to expansion members. • Discussions continue to include potential opportunities for additional municipal EV charging development.
Hourly Flex Pricing Pilot (credits for energy conservation for Ag customers) • Two customers enrolled in the program (19 meters/accounts). • The program is administered by PG&E.
• Application period closed abruptly in spring but then reopened for interested customers due to CCA concerns; however, incentive funding may soon reach capacity/limited. • First Pioneer customer “shadow bill” received and generally reflects significant customer savings.
LED Discount (discounted LEDs at local hardware stores) • More than 75% of the allocated budget for this program has been used. • Participants include 21 independent retailers and seven Dollar Tree stores, bringing the total number of participating stores to 28.
• This program continues to remain popular, with retailers providing positive feedback and continuing to provide Pioneer marketing and visibility through community partnerships.
Incentive Finder Tool
• Per Board approval at the September 18, 2025, meeting, staff entered into an agreement with PaulosAnalysis to develop a tool that provides Pioneer customers with additional ways to save money and reduce their power usage.
• Staff meet routinely with the developer, and the tool is at a beta test mode stage. • Staff are working with the developer to ensure the tool aligns with Pioneer’s brand and meets all agreed upon terms and conditions in the contract.
• The tool will be available to Pioneer customers by the end of this year.
Community Advisory Committee
• The Community Advisory Committee (CAC) meets on October 22, 2025.
Attachment 4
FY 2025-2027 Strategic Plan
Quarterly Progress Report
CEO Report
April 17, 2025
Introduction
• The plan was adopted in September 2024
• Five (5) Strategic Goals to support the
Mission and Vision
1. Be a Community Partner
2. Be Fiscally Strong & Resilient
3. Provide Exceptional Customer Service
4. Achieve Operational Optimization
5. Be a Great Place to Work
• Quarterly report focuses on progress the
past quarter with a snapshot of progress life-to-date
Summary
Community
Partner
Fiscally
Strong &
Resilient
Exceptional
Customer
Service
100
Operational
Optimization
Great Place to
Work
Overall
Be a Community Partner
• Doubled our participation year-over-year in the
HVAC and PowerShift Rewards programs
• Conducted a Contractor Day in Placer and El
Dorado Counties to build relationships with
solar contracts and promote programs
• $20,000 of sponsorships that support the
communities we serve
Be Fiscally Strong & Resilient
• Board adopted amendment to cash reserves
policy supporting maximum 270 days of cash
reserves
• Adopted FY 2025-26 Operating Budget is
balanced
• Continue expansion efforts with like-minded
communities that contribute to Pioneer’s
balance sheet
Provide Exceptional Customer
Service
• Achieved average rating of 4-starts on
Google based on reviews from ratepayers
interactions with customer service
• Continue with a minimum 4% discount to
PG&E’s generation rate
• Conducted on-site workshops to help
ratepayers understand their bill and inform
them of what Pioneer can do for them
Achieve Operational
Optimization
• Invested in software to improve day ahead
forecasting resulting in power procurement
savings
• Continued negotiations with Power Developer
for biomass project in our service territory
• Presenting various IT policies to improve our
cybersecurity
Be a Great Place to Work
• Completed triennial compensation study
• Presented health & welfare improvements to
the Board for consideration
• Hosted an end of fiscal year employee event
at Top Golf
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.