[{"_1":2,"_112":-5,"_113":-5},"loaderData",{"_3":4,"_26":27},"root",{"_5":6,"_17":10,"_18":19,"_20":21,"_22":10,"_23":-5,"_24":-5,"_25":10},"user",{"_7":8,"_9":10,"_11":10,"_12":-5,"_13":-5,"_14":15,"_16":-5},"roles",[],"isAuthenticated",false,"isPremium","planName","subscriptionStatus","featureFlags",{},"insightsBudget","isDevelopmentHost","userPreferences",{},"recaptchaSiteKey","6LcvOJcUAAAAAHsB-gPGfGktcRlKpH7OTIU_dMTD","isImpersonating","impersonation","affiliateStatus","isFreedomPortal","routes/v2/article/layout",{"_28":29,"_30":31},"notFound",true,"relatedArticles",[32,76,88,100],{"_33":34,"_35":36,"_37":38,"_39":40,"_41":42,"_43":44,"_45":46,"_47":48,"_49":50,"_51":52,"_53":54,"_55":56,"_57":58,"_59":60,"_61":62,"_63":64,"_65":66,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},"mediaId",6123874,"mediaKeyId","2687460-9dd9c5afd50730b1f7514be4c33a7cfe","parentId",2687460,"title","DERMS and FlexConnect: PG&E pilot projects aim to accelerate energization, support EV fleets and enable virtual power plants","audioSeconds",1231,"startMs",4776000,"endMs",6007000,"viewUrl","/Search/View?dp=1&key=2687460-9dd9c5afd50730b1f7514be4c33a7cfe&start=4776&end=6007","thumbnailUrl","https://assets.pipeline.soar.com/2687460-9dd9c5afd50730b1f7514be4c33a7cfe/thumbnail_4776000.jpg","articleUrl","/articles/6123874/California/DERMS-and-FlexConnect-PGE-pilot-projects-aim-to-accelerate-energization-support-EV-fleets-and-enable-virtual-power-plants","mediaUrl","https://secure.pipeline.soar.com/6123874-be213c9b862bcc7a24db9a3c7dc9d84f/orig.mp4?Expires=1771152725&Signature=Yt6ipSfi2Rqle0uzDDNyDOK1b19OJ4Wyu5AtvnSFAjLsRC8yafSiOFwYuHOEVAIMJFEhoAxdb49aUMIUmodlb4X4ov7u8JjQsfgRKXe3~9gytH0Vx7WO54VHyftPgUF5iwZJu9ovMAfJQ4B5azmNRAx0Pa-NuYfegwfv4e~sjAKIkOhdLjIXf1XDPYm4ULK0XV7VZb5Idz8YmfQQVcg2JQxcWwi3kGrpK4wKm2lftMMiOff~b-h0XxM70ntlGMN9I2FUbvlDM3VqFDYxTO-4YQPdEEwBBqgc0RE0Ua8OXPM-y6MrjnFt-PnaSMSLTfg~19auS2FNI7SCINXYdd2ubg__&Key-Pair-Id=KUT5TJCACFTXG","author","California Public Utilities Commission","date","2025-03-18T22:38:26Z","article","At the March 2025 CPUC workshop, PG&E presented progress on a distributed energy resource management system (DERMS) it says has been in production since 2023 and is already enabling operational flexibility use cases such as the FlexConnect bridging program, EV managed charging pilots and planned virtual power plant (VPP) demonstrations.

Salma (Salina) Bok, Principal Product Manager for Clean Energy Technology Platforms at PG&E, said DERMS now provides a production headend that supports IEEE 2030.5 telemetry, has 28 customer telemetry integrations for DERs 1 MW and above, and is operating FlexConnect sites that enable customers to use capacity above their static planning limits under a 72‑hour schedule and day‑ahead signaling.

One live DERMS FlexConnect example presented at the workshop showed a battery site operating under 72‑hour schedules that raised a planning limit from 2 MW to as much as 6 MW during specified windows; another example described an electric‑truck fleet that used FlexConnect to begin charging roughly 18 months earlier than the long‑term distribution upgrade timetable, saving the customer an estimated $1,000,000 in fuel costs and avoiding roughly 8,000 tons of CO2 (figures cited by PG&E for that specific customer case).

PG&E said its near‑term DERMS priorities (current GRC cycle through 2026) include scaling FlexConnect geographically and across customer types, supporting non‑wires alternatives (an NWA battery in Bakersfield is coming online), expanding EV grid integration (VGI) pilots for managed charging and vehicle‑to‑everything (V2X), and initial VPP pilots, including a summer MVP in South Bay intended to use DER dispatch to relieve overloaded substations and reduce outage risk.

Longer‑term DERMS capabilities proposed for the 2027–2030 cycle include larger‑scale FlexConnect, orchestrating VPPs across multiple modes of engagement, integrating DERMS with grid‑edge computing (for hyper‑local EV charging control and avoiding service upgrades), and improved T&D data sharing. PG&E said many DERMS use cases are supported by EPIC R&D projects and ongoing pilots that are informing scale and operational design.

PG&E emphasized that the business models and compensation mechanisms for DERs (for example, how aggregators, customers and utilities share value) remain the subject of separate proceedings and program designs; the DERMS filing in the 2027 GRC will document technology capabilities, pilot results and expected operational benefits where quantifiable.","mediaType","Video","parentTitle","PG&E Grid Modernization Plan Workshop 20250313 1913 1","oneSentenceSummary","PG&E told CPUC staff and stakeholders that its DERMS platform (deployed since 2023) is enabling FlexConnect bridging, EV managed charging pilots, non‑wires alternatives and a South Bay virtual power plant MVP, and that scaling is planned in the 2027 GRC.","taxTitle","California Public Utilities Commission, Boards and Commissions, Executive, California","taxId",77657,"location","California","headline","","shortSummary",{"_33":77,"_35":36,"_37":38,"_39":78,"_41":79,"_43":80,"_45":81,"_47":82,"_49":83,"_51":84,"_53":85,"_55":56,"_57":58,"_59":86,"_61":62,"_63":64,"_65":87,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6123879,"PG&E describes ADMS rollout and advanced distribution applications — SCADA, FLISR, VVO and state estimation",1391,6288000,7679000,"/Search/View?dp=1&key=2687460-9dd9c5afd50730b1f7514be4c33a7cfe&start=6288&end=7679","https://assets.pipeline.soar.com/2687460-9dd9c5afd50730b1f7514be4c33a7cfe/thumbnail_6288000.jpg","/articles/6123879/California/PGE-describes-ADMS-rollout-and-advanced-distribution-applications-SCADA-FLISR-VVO-and-state-estimation","https://secure.pipeline.soar.com/6123879-3520996ab2c351747f578a540d9d6ac4/orig.mp4?Expires=1771152725&Signature=Y7XbzBt1uIMeIJKGPVaIrPMpZEtSYt9~DSp2qJ7zC4jfSGXgZAODstocEc-pQF1lnPoIMUuVmw3AwgeNf~lqQtkTL0wPWHb6FS-BlJlDS28s5QM6HseMpYePQCkGkJK0sgSx37ojiRfOJ0qEowyB2uhIvlvi1Xt37dCrNBB51kwNSDqMoLSrEr~mHkvYEUgHTpTvDjJ02HWJLpkte1kmDJ24~FTToxAn24887IEMsrdnUaLbkkfr-ACwEbNabrbGIrVlRx~zEVZg~K4YeIibWgGpFLGwM-sagz~Cuv8-FjlVnAeeYGMfLqwxUaaEVCdoMaJnOnU0vdBkrwg1RrXb7w__&Key-Pair-Id=KUT5TJCACFTXG","PG&E presented an update on its Advanced Distribution Management System (ADMS) at the March 2025 CPUC workshop, saying it has moved primary SCADA operations into the ADMS platform and plans additional releases that PG&E says will yield operational efficiencies and enable advanced automation.

Chris Froff, Senior Manager for ADMS, described ADMS as a central “single pane of glass” for distribution operators. PG&E said the initial ADMS deployment began in 2018; in 2023 it implemented an ADMS SCADA pilot and migrated several regions from legacy systems. The utility said the SCADA cutover into ADMS is complete for operator displays and that it has retired the legacy RT SCADA control system as a live backup for control room operations, while some RT SCADA components will remain temporarily for RTU server management.

PG&E described three release groups: a SCADA foundation; an outage management/operations release (including outage reporting, crew dispatch and public‑safety power shutoff coordination); and advanced distribution applications that include automated fault location, isolation and service restoration (FLISR), load‑flow state estimation pilots, Volt‑VAR optimization (VVO) and integration with DERMS. The company said it is expanding FLISR to cover more feeders and will deploy OMS capabilities in 2026 to consolidate roughly 10 legacy outage‑management applications.

Chris Froff said ADMS will support improved situational awareness, reduced operator error, faster restoration and lower maintenance overhead for legacy automation products. He gave an example comparing legacy feeder‑automation (Flizzer/Yukon) programming time of roughly 40 hours per scheme under older systems to about four hours using the integrated ADMS model and automation, citing reduced servers and duplication as the source of savings.

PG&E said a pilot for low‑flow state estimation covers 14 substations and 54 feeders; load‑flow estimation is planned to scale to hundreds of feeders across 2027–2030. Volta‑VAR optimization was highlighted as a customer bill reduction opportunity through conservation voltage reduction and improved power quality; the company plans to integrate real‑time forecasting and engineering analysis into ADMS to support VVO and protection coordination.

PG&E acknowledged that many advanced benefits will accrue as later ADMS releases enter production (for example, the OMS release in 2026) and said the company intends to quantify benefits in the GRC filings where possible.","PG&E told the CPUC it has cut over SCADA to a single ADMS platform, is expanding FLISR and plans to enable Volt‑VAR optimization, load‑flow estimation and OMS consolidation in the 2027 GRC cycle.",{"_33":89,"_35":36,"_37":38,"_39":90,"_41":91,"_43":92,"_45":93,"_47":94,"_49":95,"_51":96,"_53":97,"_55":56,"_57":58,"_59":98,"_61":62,"_63":64,"_65":99,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6123881,"PG&E told CPUC it is revamping distribution planning tools — ICA, GRIP portal and EIS Part 2",2420,2770000,5190000,"/Search/View?dp=1&key=2687460-9dd9c5afd50730b1f7514be4c33a7cfe&start=2770&end=5190","https://assets.pipeline.soar.com/2687460-9dd9c5afd50730b1f7514be4c33a7cfe/thumbnail_2770000.jpg","/articles/6123881/California/PGE-told-CPUC-it-is-revamping-distribution-planning-tools-ICA-GRIP-portal-and-EIS-Part-2","https://secure.pipeline.soar.com/6123881-d811fed5664f909af1c15cd62710af08/orig.mp4?Expires=1771152725&Signature=ReMGz8ju2SVP3wyUia3AV-1SyP3chzZ--ci403DcyNxYLq3ex369Sno918xUmFTl56FrPeMTWbwdYvCI5w8ie-14a2qtUg47XftCBaoxA~i4JTvw-rKn7gMA88QFi5njynCDXa4XYQjMF27Jk0muOIpKF6S2GgvjhoXOvdwDi~y2x7M65GZJ-DihOkwkF3m~caF0JmD6A0QG12LJbsCtibkhSzwRbUK3sseHSK5RS6iHiJjDgCI93GH3FO5EY3Zh9HLKnznCTi0cFr-1-b9EUKYcfSEYrTP7pu-n7SbYqbbdS3JWctrg9DSCDsnAa~TVv2e0PGPNJz1JlKhdCfQNIA__&Key-Pair-Id=KUT5TJCACFTXG","PG&E told a March 2025 CPUC workshop that it has retooled its distribution planning toolbox for an era of rapid electrification and high distributed energy resource (DER) adoption, with planned filings and pilots tied to the 2027 general rate case.

The utility said work in the current GRC cycle delivered three main customer‑facing tools: a distribution investment/referral framework (previously a deferral focus), an Integration Capacity Analysis (ICA) for hosting capacity, and a public Grid Resource Integration Portal (GRIP). Bill Peter, Senior Manager of PG&E’s Electric Planning Modernization Group, said the company is now pivoting ICA and related tools to be more forward‑looking and customer‑facing rather than solely historical.

Peter described changes to ICA methodology: earlier ICA runs produced many zero‑capacity results; PG&E performed “grid model management” and data cleanups that improved distribution‑level results and now is developing an ICA 2 that will incorporate forecast data, known loads and planned upgrades so results are more useful to customers seeking energization or interconnection.

PG&E also said it will expand a “load ICA” use case to surface potential capacity constraints earlier in the intake process so applicants know sooner whether upgrades will be required. The company aims to launch that intake‑stage tool by the end of 2025 and to report on its effect.

The utility said it will publish more robust scenario‑based forecasting in its Electrification Impact Study Part 2 (EIS Part 2). That study will include base, equity, flexibility and bottoms‑up scenarios for 2030 and 2040, with preliminary results expected in Q3 2025 and a final report in Q4 2025. PG&E said the study will be used to integrate scenario planning into its Distribution Planning and Execution Process (DPEP).

PG&E also described revisions to its public GRIP portal to make ICA and other planning outputs more accessible, add APIs for vendor use, and integrate the portal with interconnection and energization workflows. The company reported large growth in portal use in 2023–24 and said the new backend and API capabilities are necessary to support that demand.

In Q&A, PG&E said it expects ICA 2 to be comparable in computational scale to prior ICA runs and does not foresee needing large ongoing server expansions solely to maintain monthly refresh rates once the transition is complete, though it acknowledged some short‑term migration costs and warned new use cases (for example, very large numbers of limited‑profile interconnections) could increase costs.

PG&E said ICA costs and related IT/portal expenses will be documented in its GRC workpapers and in a DRP/GRIP memo account so parties can review them in the rate case process.","PG&E presented changes to distribution planning including a forward‑looking Integration Capacity Analysis (ICA 2), a revised GRIP public portal, and an Electrification Impact Study (EIS Part 2) that will feed planning and forecasting.",{"_33":101,"_35":36,"_37":38,"_39":102,"_41":103,"_43":104,"_45":105,"_47":106,"_49":107,"_51":108,"_53":109,"_55":56,"_57":58,"_59":110,"_61":62,"_63":64,"_65":111,"_67":68,"_69":70,"_71":72,"_73":74,"_75":74},6123882,"CPUC workshop previews PG&E 10‑year grid modernization vision ahead of 2027 rate case",810,28000,838000,"/Search/View?dp=1&key=2687460-9dd9c5afd50730b1f7514be4c33a7cfe&start=28&end=838","https://assets.pipeline.soar.com/2687460-9dd9c5afd50730b1f7514be4c33a7cfe/thumbnail_28000.jpg","/articles/6123882/California/CPUC-workshop-previews-PGE-10year-grid-modernization-vision-ahead-of-2027-rate-case","https://secure.pipeline.soar.com/6123882-df50547e25294b1e76732bf360179db8/orig.mp4?Expires=1771152725&Signature=bRFu9NTi~XR3VyCTTQxCZ~AkSTVjp1CS2RIrMBWOk3tvjnqtwThJPBKyvXj21mglrELEWHn3mM8B7qw8wUGX89KGRI5jXydaLd~A31YmKFPOd3f4XolSqAvFkODdjbWzEE95WIeKKmZdbtujmfU1IavnCCLPdst~dI3JPpEGj7xehxfjMiqZ7phA4yu6MA6A81Y5FYAR6T1MWlezFyZqkqYBS2ub8E16u9siD3BqLKu~7VpU4foSpLTgRxn94jrhWjf~NBbP4FnF3I1zFWYZWVDkrWWvI4P7hmuCfVluauWGBBC4QU9uXbUa5mIlbsB0j8yBfuuPbJwJJF2NGBFVsQ__&Key-Pair-Id=KUT5TJCACFTXG","At a March 2025 online workshop hosted by the California Public Utilities Commission’s Energy Division, Pacific Gas and Electric Co. presented an updated 10‑year grid modernization vision and invited stakeholder feedback ahead of the utility’s May 15, 2025, 2027 general rate case filing.

The workshop — required under CPUC decision D18-03-023 (the GRIDMOD decision) — focused on how PG&E plans to support increasing electrification, rising distributed energy resources (DERs) and climate-driven reliability challenges while keeping costs affordable for customers.

PG&E Director Alex Portia described the filing as “a preview, and an opportunity where…we're almost there but has not been filed yet,” and said the company sought last public input before the May filing. The utility presented a “10‑year true north strategy” that places grid modernization at the center of a broader effort to deliver resiliency and decarbonization while enabling mass electrification including transportation.

Why it matters: California policy and market forces are driving rapid increases in distributed solar, storage and electric vehicle charging; PG&E told the workshop it already serves more than 600,000 electric vehicles and more than 850,000 rooftop solar customers. The company said it expects large further growth (it described an objective of 3 million EVs in its 2030 planning horizon) and argued grid modernization investments are needed to integrate that load without simply building proportionally more wires.

PG&E framed its GridMod strategy on four pillars: infrastructure upgrades (wires and automation), enhanced monitoring and control (sensors, analytics), DER grid services (using DERs for capacity, voltage support and flexibility) and DER orchestration (coordinating DERs across grid needs). Technologies the company highlighted for the next rate case chapters included distribution planning tools, an advanced distribution management system (ADMS), distributed energy resource management system (DERMS) and grid‑edge computing.

The CPUC’s Jessica Tice (Grid Planning Team) and staff noted they expect PG&E to show what has changed since the prior rate case, how proposed investments benefit ratepayers and the status of projects and budgets. PG&E said additional studies — including an Electrification Impact Study (EIS Part 2) and other scenario analyses — are underway and may be available in related proceedings, rather than fully within the GRC record.

PG&E and CPUC staff reiterated the schedule: a May 15, 2025 GRC filing by PG&E; periodic updates to CPUC Energy Division for inclusion in the 2027 legislative report due Feb. 7, 2027; and an expected next 10‑year plan refresh tied to the subsequent GRC cycle.

The workshop closed with PG&E and CPUC staff saying the presentation materials and slide deck will be posted to the CPUC Electric General Rate Case web page and that parties should submit follow‑up questions as the filing proceeds.","At a March 2025 online workshop hosted by the California Public Utilities Commission, PG&E outlined a 10‑year grid modernization vision tied to its 2027 general rate case filing, emphasizing electrification, resilience and enabling technologies such as ADMS and DERMS.","actionData","errors"]

Article not found

DERMS and FlexConnect: PG&E pilot projects aim to accelerate energization, support EV fleets and enable virtual power plants

PG&E describes ADMS rollout and advanced distribution applications — SCADA, FLISR, VVO and state estimation

PG&E told CPUC it is revamping distribution planning tools — ICA, GRIP portal and EIS Part 2

CPUC workshop previews PG&E 10‑year grid modernization vision ahead of 2027 rate case