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REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS | 6 Months Ended
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Jun. 30, 2023
Regulated Operations [Abstract] |
REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS | REGULATORY ASSETS, LIABILITIES, AND BALANCING ACCOUNTS Regulatory Assets Current Regulatory Assets As of June 30, 2023 and December 31, 2022, the Utility had current regulatory assets of $309 million and $296 million, respectively. As of June 30, 2023, current regulatory assets included approximately $100 million of deferred depreciation, interest, and tax expense related to 2022 rate base that were determined to be probable of recovery through the 2023 GRC. Long-Term Regulatory Assets Long-term regulatory assets are comprised of the following:
| Balance at
(in millions) | June 30, 2023 |  | December 31, 2022
Pension benefits (1) | $ | 109 |  |  | $ | 120 |
Environmental compliance costs | 1,204 |  |  | 1,193 |
Utility retained generation (2) | 63 |  |  | 86 |
Price risk management | 164 |  |  | 177 |
Catastrophic event memorandum account (3) | 1,272 |  |  | 1,085 |
Wildfire expense memorandum account (4) | 468 |  |  | 439 |
Fire hazard prevention memorandum account (5) | 86 |  |  | 79 |
Fire risk mitigation memorandum account (6) | 23 |  |  | 65 |
Wildfire mitigation plan memorandum account (7) | 654 |  |  | 756 |
Deferred income taxes (8) | 3,100 |  |  | 2,730 |
Insurance premium costs (9) | 11 |  |  | 99 |
Wildfire mitigation balancing account (10) | 252 |  |  | 327 |
Vegetation management balancing account (11) | 1,652 |  |  | 2,276 |
COVID-19 pandemic protection memorandum accounts (12) | 18 |  |  | 26 |
Microgrid memorandum account (13) | 141 |  |  | 213 |
Financing costs (14) | 203 |  |  | 211 |
SB 901 securitization (15) | 5,296 |  |  | 5,378 |
AROs in excess of recoveries (16) | — |  |  | 120 |
Other | 1,247 |  |  | 1,063 |
Total long-term regulatory assets | $ | 15,963 |  |  | $ | 16,443 |
(1) Payments into the pension and other benefits plans are based on annual contribution requirements. As these annual requirements continue indefinitely into the future, the Utility expects to continuously recover pension benefits. (2) In connection with the settlement agreement entered into among PG&E Corporation, the Utility, and the CPUC in 2003 to resolve the Utility’s 2001 proceeding under Chapter 11, the CPUC authorized the Utility to recover $1.2 billion of costs related to the Utility’s retained generation assets. The individual components of these regulatory assets are being amortized over the respective lives of the underlying generation facilities, consistent with the period over which the related revenues are recognized. (3) Includes costs of responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities. The increase in the CEMA regulatory asset from December 31, 2022 to June 30, 2023 is primarily due to costs incurred for repair and restoration work performed related to an increase in declared winter storm events in the Utility’s service area. As of June 30, 2023 and December 31, 2022, $45 million and $44 million in COVID-19 related costs were recorded to CEMA regulatory assets, respectively. Recovery of CEMA costs is subject to CPUC review and approval. (4) Represents incremental wildfire claims and outside legal expenses related to the 2021 Dixie fire and the 2022 Mosquito fire. Recovery of WEMA costs is subject to CPUC review and approval. (5) Includes costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards associated with overhead power line facilities and nearby aerial communication facilities that have not been previously authorized in another proceeding. Recovery of FHPMA costs is subject to CPUC review and approval. (6) Includes incremental costs associated with fire risk mitigation. Recovery of FRMMA costs is subject to CPUC review and approval. (7) Includes costs associated with the 2020 WMP for the period of January 1, 2020 through December 31, 2020, the 2021 WMP for the period of January 1, 2021 through December 31, 2021, the 2022 WMP for the period of January 1, 2022 through December 31, 2022, and the 2023 WMP for the period of January 1, 2023 through June 30, 2023. Also includes the noncurrent portion of costs associated with the 2019 WMP that were approved for recovery per the 2020 WMCE final decision. Recovery of WMPMA costs is subject to CPUC review and approval. (8) Represents cumulative differences between amounts recognized for ratemaking purposes and expense recognized in accordance with GAAP. (9) Represents excess liability insurance premium costs recorded to RTBA and adjustment mechanism for costs determined in other proceedings, as authorized in the 2020 GRC and 2019 GT&S rate cases, respectively. (10) Includes costs associated with certain wildfire mitigation activities for the period of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 115% of adopted revenue requirements, which are subject to CPUC review and approval. (11) Includes costs associated with certain vegetation management activities for the period of January 1, 2020 through June 30, 2023. The noncurrent balance represents costs above 120% of adopted revenue requirements, which are subject to CPUC review and approval. (12) Includes costs associated with customer protections, including higher uncollectible costs related to the moratorium on electric and gas service disconnections program implementation costs, and higher accounts receivable financing costs for the period of March 4, 2020 to September 30, 2021. As of June 30, 2023, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $14 million is associated with program costs and higher accounts receivable financing costs. As of December 31, 2022, the Utility had recorded uncollectibles in the amount of $4 million for small business customers. The remaining $22 million is associated with program costs and higher accounts receivable financing costs. Recovery of CPPMA costs is subject to CPUC review and approval. (13) Includes costs associated with temporary generation, infrastructure upgrades, and community grid enablement programs associated with the implementation of microgrids. Amounts incurred are subject to CPUC review and approval. (14) Includes costs associated with long-term debt financing deemed recoverable under ASC 980 more than twelve months from the current date. These costs and their amortization period are reviewable and approved in the Utility’s cost of capital or other regulatory filings. (15) In connection with the SB 901 securitization, the CPUC authorized the issuance of one or more series of recovery bonds in connection with the post-emergence transaction to finance $7.5 billion of claims associated with the 2017 Northern California wildfires. The balance represents PG&E Wildfire Recovery Funding LLC’s right to recover $7.5 billion in wildfire claims costs associated with the 2017 Northern California wildfires, partially offset by the $2.0 billion in required upfront shareholder contributions to the customer credit trust, net of amortization since inception. The recovery bonds are being paid through fixed recovery charges, which are designed to recover the full scheduled principal amount of the recovery bonds along with any associated interest and financing costs. See Note 5 below. (16) Represents the cumulative differences between ARO expenses and amounts collected in rates. Decommissioning costs related to the Utility’s nuclear facilities are recovered through rates and are placed in nuclear decommissioning trusts. This regulatory asset also represents the deferral of realized and unrealized gains and losses on these nuclear decommissioning trust investments. See Note 9 below. Regulatory Liabilities Long-term regulatory liabilities are comprised of the following:
| Balance at
(in millions) | June 30, 2023 |  | December 31, 2022
Cost of removal obligations (1) | $ | 8,023 |  |  | $ | 7,773 |
Public purpose programs (2) | 1,225 |  |  | 1,062 |
Employee benefit plans (3) | 918 |  |  | 904 |
Transmission tower wireless licenses (4) | 421 |  |  | 430 |
SFGO sale (5) | 224 |  |  | 264 |
SB 901 securitization (6) | 6,127 |  |  | 5,800 |
Wildfire self-insurance (7) | 200 |  |  | — |
Other | 1,380 |  |  | 1,397 |
Total long-term regulatory liabilities | $ | 18,518 |  |  | $ | 17,630 |
(1) Represents the cumulative differences between the recorded costs to remove assets and amounts collected in rates for expected costs to remove assets. (2) Represents amounts received from customers designated for public purpose program costs expected to be incurred beyond the next 12 months, primarily related to energy efficiency programs. (3) Represents cumulative differences between incurred costs and amounts collected in rates for post-retirement medical, post-retirement life and long-term disability plans. (4) Represents the portion of the net proceeds received from the sale of transmission tower wireless licenses that will be returned to customers through 2042. Of the $421 million, $294 million will be refunded to FERC-jurisdictional customers, and $127 million will be refunded to CPUC-jurisdictional customers. (5) Represents the noncurrent portion of the net gain on the sale of the SFGO, which closed on September 17, 2021, that will be distributed to customers over a five-year period that began in 2022. (6) In connection with the SB 901 securitization, the Utility is required to return up to $7.59 billion of certain shareholder tax benefits to customers via periodic bill credits over the life of the recovery bonds. The balance reflects qualifying shareholder tax benefits that PG&E Corporation is obligated to contribute to the customer credit trust, net of amortization since inception, and is expected to increase as additional qualifying amounts are recognized, including when the Fire Victim Trust sells additional shares. PG&E Corporation will continue to separately recognize tax benefits within income tax expense on the income statement when the Fire Victim Trust sells additional shares. See Note 5 below. (7) Represents amounts received from customers designated for wildfire self-insurance. See Note 10 below. Regulatory Balancing Accounts Current regulatory balancing accounts receivable and payable are comprised of the following:
| Balance at
(in millions) | June 30, 2023 |  | December 31, 2022
Electric distribution (1) | $ | 1,289 |  |  | $ | 448 |
Electric transmission (2) | 117 |  |  | 96 |
Gas distribution and transmission (3) | 62 |  |  | 72 |
Energy procurement (4) | 1,032 |  |  | 684 |
Public purpose programs (5) | 300 |  |  | 358 |
Fire hazard prevention memorandum account (6) | 129 |  |  | — |
Wildfire mitigation plan memorandum account (7) | 78 |  |  | — |
Wildfire mitigation balancing account (8) | 96 |  |  | 2 |
Vegetation management balancing account (9) | 872 |  |  | 137 |
Insurance premium costs (10) | 268 |  |  | 602 |
Residential uncollectibles balancing accounts (11) | 228 |  |  | 126 |
Catastrophic event memorandum account (12) | 332 |  |  | 144 |
Other | 580 |  |  | 595 |
Total regulatory balancing accounts receivable | $ | 5,383 |  |  | $ | 3,264 |
| Balance at
(in millions) | June 30, 2023 |  | December 31, 2022
Electric transmission (2) | $ | 222 |  |  | $ | 228 |
Gas distribution and transmission (3) | 449 |  |  | 66 |
Energy procurement (4) | 8 |  |  | 428 |
Public purpose programs (5) | 257 |  |  | 272 |
SFGO sale | 75 |  |  | 152 |
Other | 306 |  |  | 512 |
Total regulatory balancing accounts payable | $ | 1,317 |  |  | $ | 1,658 |
(1) The electric distribution accounts track the collection of revenue requirements approved in the GRC and other proceedings. (2) The electric transmission accounts track recovery of costs related to the transmission of electricity approved in the FERC TO rate cases. (3) The gas distribution and transmission accounts track the collection of revenue requirements approved in the GRC and the GT&S rate case and other proceedings. (4) Energy procurement balancing accounts track recovery of costs related to the procurement of electricity and other revenue requirements approved by the CPUC for recovery in procurement-related balancing accounts, including any environmental compliance-related activities. (5) The Public purpose programs balancing accounts are primarily used to record and recover authorized revenue requirements for CPUC-mandated programs such as energy efficiency. (6) The FHPMA tracks costs associated with the implementation of regulations and requirements adopted to protect the public from potential fire hazards approved for cost recovery in the 2020 WMCE final decision. (7) The WMPMA tracks costs associated with the 2019 WMP which were approved for cost recovery in the 2020 WMCE final decision. (8) The WMBA tracks costs associated with wildfire mitigation revenue requirement activities approved for cost recovery. (9) The VMBA tracks routine and enhanced vegetation management activities approved for cost recovery. (10) The insurance premium costs track the current portion of incremental excess liability insurance costs recorded to RTBA and adjustment mechanism for costs determined in other proceedings, as authorized in the 2020 GRC and 2019 GT&S rate cases, respectively. In addition to insurance premium costs recorded in Regulatory balancing accounts receivable and in Long-term regulatory assets above, as of June 30, 2023, and December 31, 2022 there were $7 million and $48 million, respectively, in insurance premium costs recorded in Current regulatory assets. (11) The RUBA tracks costs associated with customer protections, including higher uncollectible costs related to a moratorium on electric and gas service disconnections for residential customers. (12) The CEMA tracks costs associated with responding to catastrophic events that have been declared a disaster or state of emergency by competent federal or state authorities approved for cost recovery in the 2018 CEMA and 2020 WMCE final decisions. For more information, see Note 4 of the Notes to the Consolidated Financial Statements in Item 8 of the 2022 Form 10-K.

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