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  "description": "R.25-06-019 · Proposed Decision · Attachment A\n\n\n\nPROCUREMENT OBLIGATIONS BY LOAD SERVING ENTITY\n\n\nNet Qualifying Capacity targets for 2030 and 2032 compliance years\n\n\n\n\n\n6,000\nTotal MW NQC\n\n\n31\nLSEs\n\n\n177K\nGWh 2026 Load\n\n\n\n\n\n\n\n\n\n\n\nLoad Serving Entity\nType\n2026 Load (GWh)\nAdj. Share\n2030 MW NQC\n2032 MW NQC\nTotal MW NQC\n\n\n\n\n\n\nPacific Gas and Electric (bundled)\nIOU\n5,144\n\n\n\n17.3%\n\n\n347\n694\n1,041\n\n\n\nPG&E Direct Access (aggregated)*\nESP\n11,393\n\n\n\n4.1%\n\n\n82\n164\n245\n\n\n\nClean Power San Francisco\nCCA...",
  "path": "/february-26-2026-cpuc-voting-meeting-preview-irp-6-000-mw-order-closure-on-winter-gas-price-investigation/",
  "publishedAt": "2026-02-19T20:58:01.000Z",
  "site": "https://www.calregulatory.com",
  "tags": [
    "**February 26** voting meeting",
    "Vehicle-to-Everything",
    "Redwood Coast Airport Microgrid",
    "proposed decision",
    "Integrated Energy Policy Report",
    "SERVM",
    "RPS",
    "ELCC",
    "accompanying attachment",
    "Reliable and Clean Power Procurement Program",
    "I.23-03-008",
    "Subscribe now"
  ],
  "textContent": "The CPUC's **February 26** voting meeting is set to include significant decisions in the Integrated Resource Planning docket and the Natural Gas Price Spike investigation.\n\n  * A proposed decision in the IRP orders **2,000 MW** of Net Qualifying Capacity by 2030, and an additional **4,000 MW** by 2032,**** with no more than half of each tranche met by storage.\n  * A PD in the Price Spike investigation treats the winter 2022–2023 gas price spike as a system-level stress event rather than a failure of utility conduct.\n\n\n\nThe remainder of the agenda includes actions related to the Electric Program Investment Charge (EPIC), PG&E's Vehicle-to-Everything Microgrid Pilot at the Redwood Coast Airport Microgrid, and two SDG&E mid-term reliability contracts resulting from the company's Tranche 3 solicitation, authorizing **92 MW** of standalone battery storage projects.\n\n* * *\n\n### INTEGRATED RESOURCE PLANNING\n\nA proposed decision requires California load-serving entities to procure additional clean reliability resources to address forecasted system needs in the 2029–2032 period.\n\nThe PD orders **2,000 MW** of NQC online by **June 1, 2030** , and an additional **4,000 MW** by **June 1, 2032** , with no more than half of each tranche met by storage. The PD also transmits updated base and sensitivity portfolios to the CAISO for use in its 2026–2027 Transmission Planning Process.\n\nThe procurement finding is based on updated Integrated Energy Policy Report load forecasts, reliability modeling using SERVM, and the risk of delayed long-lead-time resources. Eligible resources must follow the Mid-Term Reliability framework and be new, non-GHG-emitting and/or RPS-eligible, with limited credit for repowering only to the extent of incremental capacity added.\n\nThe PD does not impose a separate energy-procurement mandate, relying instead on ELCC-based capacity requirements and existing RPS and Resource Adequacy programs.\n\n  * An accompanying attachment allocates the 6,000 MW NQC obligation across investor-owned utilities, Community Choice Aggregators, and aggregated Electric Service Providers based on adjusted 2026 load shares (see table below).\n  * The largest shares fall on PG&E and SCE bundled service, followed by major CCAs such as Clean Power Alliance, East Bay Community Energy, and San Diego Community Power. ESP obligations are shown only in aggregate and will be conveyed confidentially to individual providers within two weeks of the decision's adoption.\n\nCRI Procurement Table Preview\n\nR.25-06-019 · Proposed Decision · Attachment A\n\n## Procurement Obligations by Load Serving Entity\n\nNet Qualifying Capacity targets for 2030 and 2032 compliance years\n\n6,000 Total MW NQC\n\n31 LSEs\n\n177K GWh 2026 Load\n\nLoad Serving Entity | Type | 2026 Load (GWh) | Adj. Share | 2030 MW NQC | 2032 MW NQC | Total MW NQC\n---|---|---|---|---|---|---\nPacific Gas and Electric (bundled) | IOU | 5,144 |  17.3% | 347 | 694 | 1,041\nPG&E Direct Access (aggregated)* | ESP | 11,393 |  4.1% | 82 | 164 | 245\nClean Power San Francisco | CCA | 3,394 |  1.7% | 34 | 68 | 103\nEast Bay Community Energy | CCA | 9,432 |  4.7% | 95 | 190 | 285\nKing City Community Power | CCA | 36 |  0.0% | 0.4 | 1 | 1\nMarin Clean Energy | CCA | 5,966 |  3.0% | 60 | 120 | 180\nCentral Coast Community Energy | CCA | 5,791 |  2.9% | 58 | 117 | 175\nPeninsula Clean Energy Authority | CCA | 3,831 |  1.9% | 39 | 77 | 116\nPioneer Community Energy | CCA | 1,793 |  0.9% | 18 | 36 | 54\nRedwood Coast Energy Authority | CCA | 634 |  0.3% | 6 | 13 | 19\nSan Jose Clean Energy | CCA | 4,543 |  2.3% | 46 | 91 | 137\nSilicon Valley Clean Energy | CCA | 4,132 |  2.1% | 42 | 83 | 125\nSonoma Clean Power Authority | CCA | 2,236 |  1.1% | 23 | 45 | 68\nValley Clean Energy Alliance | CCA | 724 |  0.4% | 7 | 15 | 22\nSouthern California Edison (bundled) | IOU | 51,858 |  35.8% | 716 | 1,431 | 2,147\nSCE Direct Access (aggregated)* | ESP | 12,003 |  4.3% | 86 | 172 | 259\nApple Valley Choice Energy | CCA | 250 |  0.1% | 3 | 5 | 8\nCity of Pomona | CCA | 431 |  0.2% | 4 | 9 | 13\nClean Power Alliance of Southern California | CCA | 11,166 |  5.6% | 112 | 225 | 337\nDesert Community Energy | CCA | 369 |  0.2% | 4 | 7 | 11\nLancaster Clean Energy | CCA | 618 |  0.3% | 6 | 12 | 19\nOrange County Power Authority | CCA | 2,275 |  1.1% | 23 | 46 | 69\nEnergy for Palmdale's Independent Choice | CCA | 497 |  0.3% | 5 | 10 | 15\nPico Rivera Innovative Municipal Energy | CCA | 218 |  0.1% | 2 | 4 | 7\nRancho Mirage Energy Authority | CCA | 286 |  0.1% | 3 | 6 | 9\nSan Jacinto Power | CCA | 172 |  0.1% | 2 | 3 | 5\nSanta Barbara Clean Energy | CCA | 347 |  0.2% | 3 | 7 | 10\nSan Diego Gas & Electric (bundled) | IOU | 2,658 |  1.8% | 37 | 73 | 110\nSDG&E Direct Access (aggregated)* | ESP | 3,942 |  1.4% | 28 | 57 | 85\nClean Energy Alliance | CCA | 2,492 |  1.3% | 25 | 50 | 75\nSan Diego Community Power | CCA | 8,340 |  4.2% | 84 | 168 | 252\nTotal — All LSEs |  | 176,972 |  100% | 2,000 | 4,000 | 6,000\n\nKEY IOU Investor-Owned Utility CCA Community Choice Aggregator ESP Electric Service Provider\n\n***ESP Note:** Procurement obligations for electric service providers are presented in aggregate. Individual ESP obligations remain confidential and will be conveyed to each ESP within two weeks of adoption.\n\n**INSTANT ANALYSIS:** On resource eligibility, the PD excludes fossil resources, limits repowering to incremental capacity only, and permits energy-only resources solely when co-located with fully deliverable storage. The 50% storage cap is the central policy choice: it constrains over-reliance on storage and indirectly drives additional energy procurement without reopening the Renewables Portfolio Standard or imposing a separate energy mandate.\n\nWhy the PD matters for CRI readers: it establishes the next reliability obligation after Mid-Term Reliability, shapes procurement behavior through 2032, and feeds directly into the CAISO's transmission approvals with cost-recovery implications. The PD also creates a narrow window for projects to secure remaining federal incentives, increasing near-term procurement pressure even as**** the Reliable and Clean Power Procurement Program remains under development.\n\n* * *\n\n### NATURAL GAS PRICE SPIKE INVESTIGATION\n\nA proposed decision in I.23-03-008 finds that the winter 2022–2023 natural gas price spike resulted from a convergence of adverse market conditions, not misconduct by regulated utilities or storage providers.\n\n### This post is for subscribers only\n\nBecome a member to get access to all content\n\nSubscribe now",
  "title": "February 26, 2026 CPUC Voting Meeting Preview: IRP 6,000 MW Order; Closure on Winter Gas Price Investigation",
  "updatedAt": "2026-02-21T02:53:50.156Z"
}