10-Q: PG&E Q3 2025 Earnings: Wildfire Costs & Rate Relief Drive Results

PG&E Corporation reports increased net income for Q3 2025, driven by DCPP extended operations and wildfire mitigation rate relief, amidst ongoing wildfire liabilities and regulatory proceedings.

Summary

• PG&E Corporation's net income available for common shareholders increased to $823 million for the three months ended September 30, 2025, up from $576 million in the same period of 2024.
• For the nine months ended September 30, 2025, PG&E Corporation's net income available for common shareholders rose to $1,951 million, compared to $1,828 million in the prior year.
• The Utility's total operating revenues increased by $309 million, or 5%, in the three months ended September 30, 2025, primarily due to approximately $150 million from extended operations at Diablo Canyon Power Plant (DCPP) and $140 million in interim rate relief from the 2023 Wildfire Mitigation and Catastrophic Events (WMCE) proceeding.
• Utility operating and maintenance expenses decreased by $42 million, or 2%, in Q3 2025, mainly due to the absence of $210 million in FERC-ordered vegetation management capitalization costs recorded in Q3 2024, partially offset by DCPP extended operations costs and deferred expense recognition.
• Wildfire-related claims, net of recoveries, decreased significantly to $1 million in Q3 2025 from $74 million in Q3 2024, primarily due to the absence of 2019 Kincade fire charges comparable to the prior year.
• Wildfire Fund expense decreased by $53 million, or 38%, in Q3 2025 and $24 million, or 8%, for the nine months, attributed to lower accelerated amortization associated with the 2021 Dixie fire receivable.
• The Utility's income tax benefit increased to $202 million in Q3 2025 from $70 million in Q3 2024, and for the nine months, it shifted to a $100 million benefit from a $90 million expense, mainly due to increased tax repairs deduction and additional deductions for electric generation costs.
• Net cash provided by operating activities for the Utility increased by $0.7 billion, or 12%, during the nine months ended September 30, 2025, driven by increased collections related to DCPP extended operations and 2023 WMCE interim rate relief, lower non-wildfire insurance costs, and decreased wildfire-related payments.
• Cash used in investing activities for the Utility increased by $1.0 billion, or 13%, during the nine months, primarily due to a $349 million payment for the Oakland headquarters purchase and increased investments in undergrounding and distribution poles for the Wildfire Mitigation Plan (WMP).
• As of September 30, 2025, PG&E Corporation and the Utility had recorded aggregate liabilities of $1.325 billion for the 2019 Kincade fire, $2.125 billion for the 2021 Dixie fire, and $250 million for the 2022 Mosquito fire, all before available insurance and other probable cost recoveries.
• The Utility has recorded insurance receivables of $523 million for the 2021 Dixie fire and $256 million for the 2022 Mosquito fire, and a Wildfire Fund receivable of $1.125 billion for the 2021 Dixie fire, of which $609 million had been received.
• Total liquidity as of September 30, 2025, was approximately $6.1 billion, comprising $253 million of the Utility's cash, $151 million of PG&E Corporation's cash, and $5.7 billion of availability under revolving credit facilities.
• Senate Bill 254 (SB 254) became law on September 19, 2025, establishing the Continuation Account to provide up to $18 billion of additional liquidity for catastrophic wildfire-related claims if the Wildfire Fund is depleted.

Sentiment

Score: 7

Explanation: The company reported increased net income and operating cash flows, indicating improved financial health. Key regulatory approvals for rate relief and cost recovery, along with successful debt and equity financings, provide a stable outlook for capital investments. However, substantial existing wildfire liabilities and the inherent uncertainties of future wildfire risks and regulatory interpretations remain significant concerns.

Positives

• PG&E Corporation's net income available for common shareholders increased to $823 million in Q3 2025 from $576 million in Q3 2024, and to $1,951 million for the nine months from $1,828 million.
• The Utility's net income available for common stock increased to $910 million in Q3 2025 from $615 million in Q3 2024, and to $2,210 million for the nine months from $1,954 million.
• Total operating revenues for the Utility increased by $309 million (5%) in Q3 2025, driven by DCPP extended operations and interim rate relief.
• Net cash provided by operating activities for the Utility increased by $0.7 billion (12%) during the nine months ended September 30, 2025.
• Wildfire-related claims, net of recoveries, decreased significantly in Q3 2025 to $1 million from $74 million in Q3 2024.
• Wildfire Fund expense decreased by $53 million (38%) in Q3 2025 and $24 million (8%) for the nine months, due to lower accelerated amortization.
• The Utility's income tax provision shifted to a benefit of $202 million in Q3 2025 from a benefit of $70 million in Q3 2024, and to a benefit of $100 million for the nine months from an expense of $90 million, primarily due to increased tax deductions.
• The Utility successfully completed debt financings, including $1.0 billion and $750 million First Mortgage Bonds in February 2025, and additional bonds in June and October 2025, to repay existing debt and for general corporate purposes.
• The Utility's revolving credit agreement maturity was extended to June 21, 2030, and aggregate commitments increased from $4.4 billion to $5.4 billion.
• PG&E Corporation's revolving credit agreement maturity was extended to June 22, 2028, and aggregate commitments increased from $500 million to $650 million.
• SB 254 became law, establishing the Continuation Account with up to $18 billion of additional liquidity for catastrophic wildfire claims.
• FERC issued a final order approving an all-party settlement of the Utility's transmission owner rate case for 2024 (TO21).
• CPUC issued a final decision increasing the cost cap for 2025 and 2026 by an aggregate $2.38 billion in connection with Energization Timelines.
• CPUC issued a final decision approving $1.06 billion in cost recovery in the 2022 WMCE proceeding.
• PG&E Corporation has completed the planned equity financing for its $73 billion capital expenditure plan for 2026 through 2030.

Negatives

• PG&E Corporation and the Utility continue to carry significant liabilities for past wildfires: $1.325 billion for the 2019 Kincade fire, $2.125 billion for the 2021 Dixie fire, and $250 million for the 2022 Mosquito fire (all before available insurance/recoveries).
• The Utility has identified instances of noncompliance with legal and regulatory requirements related to wildfire mitigation efforts, which could lead to fines, penalties, or enforcement actions.
• The potential for the Utility's equipment to be involved in future catastrophic wildfires remains significant, exacerbated by climate change.
• Interest income for the Utility decreased by $62 million (41%) in Q3 2025 and $102 million (21%) for the nine months, due to lower interest rates and interest-bearing account balances.
• Cash used in investing activities for the Utility increased by $1.0 billion (13%) during the nine months, partly due to the Oakland headquarters purchase and increased WMP investments.
• Net cash provided by financing activities for the Utility decreased by $383 million (17%) during the nine months, primarily due to no similar AB 1054 recovery bonds issuance in 2025 compared to 2024, increased long-term debt repayments, and decreased DWR loan proceeds and equity contributions.
• The Wildfire Fund and Continuation Account funds could be depleted more quickly than expected due to claims made by other participating electric utility companies.
• The revised prudency standard under AB 1054 has not been fully interpreted or applied by the CPUC, creating uncertainty for the Utility's ability to recover all or a portion of expenses recorded as receivables.
• FERC denied the 0.5% ROE adder for CAISO participation in the TO21 rate case, and subsequent appeals to the Ninth Circuit and a petition for certiorari to the Supreme Court were unsuccessful or are pending.
• The CPUC's final decision for the 2022 WMCE proceeding disallowed $217 million in Vegetation Management Balancing Account (VMBA) costs.
• Decisions in General Rate Case (GRC) proceedings have historically been delayed, which may cause the Utility's spending to exceed authorized amounts without an ability to seek cost recovery for such excess.
• An ongoing IRS audit for tax years 2015-2018 includes a significant unresolved matter regarding the deductibility of approximately $850 million in San Bruno-related safety spend and $400 million in customer bill credits, leading to a $70 million decrease in PG&E Corporation's income tax benefit in 2024.
• Wildfire-related securities litigation and indemnification obligations could result in material losses or the issuance of a material number of common shares.

Risks

• The extent to which the Wildfire Fund, the Continuation Account, and the revised prudency standard under AB 1054 effectively mitigate the risk of liability for damages arising from catastrophic wildfires, including whether the Utility maintains an approved WMP and a valid safety certification and whether the Wildfire Fund or the Continuation Account has sufficient remaining funds.
• Risks and uncertainties associated with wildfires that have occurred or may occur in the Utility's service area, including the 2019 Kincade fire, 2021 Dixie fire, and 2022 Mosquito fire, the damage caused, the extent of the Utility's liability (including inverse condemnation), investigations, potential fines or penalties, and the inability to recover costs.
• The effectiveness of the Utility's wildfire mitigation initiatives, including system hardening (undergrounding), the cost of the program, and the timing and outcome of cost recovery proceedings.
• The Utility's ability to safely, reliably, and efficiently construct, maintain, operate, protect, and decommission its facilities, and provide electricity and natural gas services safely and reliably.
• Significant changes to the electric power and natural gas industries driven by technological advancements, electrification, decarbonization, reductions in Utility customer demand for natural gas, and impacts of growing distributed and renewable generation resources.
• Cyber or physical attacks on the Utility or its third-party vendors, contractors, or customers, which could result in operational disruption, data loss, remediation costs, litigation, or reputational harm.
• The Utility's ability to attract or retain specialty personnel.
• The impact of severe weather events and other natural disasters, including wildfires, storms, floods, extreme heat, and earthquakes, which can cause unplanned outages, disrupt service, or damage facilities, and the effectiveness of mitigation efforts.
• Existing and future regulation and federal, state, or local legislation, their implementation and interpretation, and the cost to comply with such regulation and legislation, including those regarding wildfires, the environment, and the nuclear industry.
• The outcome of current and future self-reports, investigations, or other enforcement actions related to the Utility's compliance with laws, rules, regulations, or orders applicable to its operations.
• The timing and outcomes of the Utility's pending and future ratemaking and regulatory proceedings, including the ability to recover costs through rates and the transfer of ownership of assets to municipalities.
• Whether the Utility can control its operating costs within authorized levels of spending and achieve projected savings, and the impact of inflation, import tariffs, and changes in cost forecasts.
• The risks and uncertainties associated with PG&E Corporation's and the Utility's substantial indebtedness and the limitations on their operating flexibility.
• The risks and uncertainties associated with the resolution of wildfire-related securities litigation and indemnification obligations.
• The ultimate amount of unrecoverable environmental costs the Utility incurs associated with its natural gas compressor station site near Hinkley, California, and its fossil fuel-fired generation sites.
• The supply and price of electricity, natural gas, and nuclear fuel, and the Utility's ability to manage and respond to volatility of energy commodity prices and recover costs through rates.
• The ability of PG&E Corporation and the Utility to access capital markets and other sources of debt and equity financing in a timely manner on acceptable terms, and volatility in such capital markets and changes in interest rates.
• The risks and uncertainties associated with high rates for the Utility's customers.
• Actions by credit rating agencies to downgrade PG&E Corporation's or the Utility's credit ratings.
• The severity, extent, and duration of pandemics and the Utility's ability to collect on customer receivables.
• The impact of changes in GAAP, standards, rules, or policies, including those related to regulatory accounting, and the impact of changes in their interpretation or application.
• Environmental violations alleged in connection with the 2020 CZU Lightning Complex fire and the 2023 Butte Canal breach, which could result in penalties and remediation costs.
• The IRS audit of tax returns for 2015-2018, particularly regarding the deductibility of San Bruno-related safety spend and customer bill credits, which could result in additional tax liabilities.

Future Outlook

PG&E Corporation and the Utility expect to generate and obtain adequate cash to meet their short-term and long-term cash requirements, primarily through capital and credit markets, as capital expenditures, debt maturities, and dividends are expected to exceed operating cash flows. The Utility estimates $13.2 billion in capital expenditures for 2025 and proposes $45.0 billion in CPUC-jurisdictional asset investments between 2027 and 2030, including annual undergrounding of 307 miles of electrical lines. The company anticipates beginning to account for the Continuation Account once the Wildfire Fund administrator deems it necessary and the CPUC approves the extension of non-bypassable charges. The Utility expects to amortize SB 901 securitization regulatory assets and liabilities over the life of the recovery bonds and plans to recover $1.1 billion of environmental remediation liability through ratemaking mechanisms. Regulatory decisions for the 2027 GRC are expected by May 2027, and for the 2026 Cost of Capital application in 2025. The Utility is unable to predict the timing or amount of future funds from the DOE Loan Guarantee Agreement due to recent changes in administration.

Management Comments

• PG&E Corporation and the Utility believe that their financial condition, results of operations, liquidity, and cash flows may be materially affected by the uncertainties in connection with wildfires, wildfire mitigation, and associated cost recovery.
• The Utility has set a long-term goal to increase its capital investments to meet safety and climate goals, while also achieving operating cost savings through improved planning and execution, including waste elimination through the Lean operating system.
• PG&E Corporation and the Utility work to reduce financing costs by identifying and executing on opportunities to efficiently finance the business, which depends on capital market conditions.
• PG&E Corporation and the Utility expect to be able to generate and obtain adequate cash to meet their cash requirements in the short term and in the long term.
• PG&E Corporation and the Utility intend to vigorously defend themselves against both criminal charges and civil complaints related to wildfires.
• PG&E Corporation and the Utility disagree with many allegations in the Cal Fire Investigation Report regarding the 2021 Dixie fire and plan to vigorously contest them.
• PG&E Corporation and the Utility intend to continue to review available information and other information as it becomes available regarding wildfire investigations.
• PG&E Corporation and the Utility do not believe that the resolution of matters related to the CZU Lightning Complex Fire Notices of Violation or the Butte Canal Breach will have a material impact on their financial condition, results of operations, or cash flows.

Industry Context

The filing underscores the persistent challenges faced by California's investor-owned utilities, particularly the financial and operational burdens of catastrophic wildfires, which are exacerbated by climate change. The legislative responses, such as the Wildfire Fund and the newly established Continuation Account (SB 254), reflect a unique regulatory framework designed to stabilize utilities while mandating significant investments in wildfire mitigation, including system hardening and undergrounding. This approach aims to balance public safety, grid reliability, and financial viability in a high-risk environment. The company's efforts to extend DCPP operations and manage natural gas demand shifts also highlight the broader industry's navigation of decarbonization goals, energy transition, and the increasing demand for electricity from sectors like data centers and transportation electrification.

Legal Proceedings

• **2019 Kincade Fire**: Cal Fire determined the Utility's equipment caused the fire. As of October 15, 2025, approximately 135 complaints on behalf of at least 3,014 plaintiffs are ongoing. A settlement agreement was reached with Geysers Power Company, Calpine Corporation, and CPN Insurance Corporation. A tolling agreement with Cal OES remains in effect. The Utility has recorded a $1.325 billion liability (before available insurance).
• **2021 Dixie Fire**: Cal Fire determined the fire was caused by a tree contacting the Utility's electrical distribution lines. As of October 15, 2025, approximately 186 complaints on behalf of at least 8,919 individual plaintiffs are ongoing. Cal Fire filed a complaint for suppression and investigation costs, and the Utility's petition for writ of mandate regarding a court ruling on Cal Fire's demurrer is pending. A putative class complaint is ongoing, with a deadline of December 1, 2025, for plaintiffs to move for class certification. A tolling agreement with Cal OES remains in effect. The Utility has recorded a $2.125 billion liability (before available recoveries).
• **2022 Mosquito Fire**: The USFS is investigating the cause, with an initial assessment pointing to the Utility's power line. As of October 15, 2025, approximately 30 complaints on behalf of at least 2,956 individual plaintiffs are ongoing. The Utility filed cross-complaints against Placer County Water Agency (PCWA). Cal Fire filed a complaint for fire suppression and investigation costs. A tolling agreement with Cal OES remains in effect. Individual claimant bellwether trial dates are set for April 13, 2026. The Utility has recorded a $250 million liability (before available insurance).
• **Wildfire-Related Securities Litigation**: Consolidated class actions (In re PG&E Corporation Securities Litigation) and a separate action (Orbis Capital Limited et al., v. Williams et al.) are ongoing against certain former officers, directors, and underwriters. The District Court granted motions to dismiss the third amended complaint with leave to amend by October 30, 2025. Subordinated Claims filed in the bankruptcy process are being resolved in accordance with the Plan, potentially leading to material losses or the issuance of common stock.
• **Butte County District Attorney's Office Investigation into the 2018 Camp Fire**: The Utility pleaded guilty to 84 counts of involuntary manslaughter and one count of unlawfully causing a fire. A hearing on the status of restitution, involving funds from the Fire Victim Trust, has been continued to November 14, 2025.
• **CZU Lightning Complex Fire Notices of Violation**: Several governmental entities raised concerns regarding the Utility's emergency response to the 2020 fire, alleging environmental, vegetation management, and unpermitted work violations. The Utility has recorded immaterial charges and believes the resolution will not materially impact its financial condition, results of operations, or cash flows.
• **Butte Canal Breach**: The Central Valley Regional Water Quality Control Board has alleged environmental violations in connection with a canal breach on August 9, 2023. The Utility believes a liability is probable but not reasonably estimable, and does not believe the resolution will have a material impact on its financial condition, results of operations, or cash flows.
• **IRS Audit**: The IRS is auditing PG&E Corporation's tax returns for 2015 through 2018. A significant unresolved matter relates to the deductibility of approximately $850 million in San Bruno-related safety spend and $400 million in customer bill credits. PG&E Corporation decreased its income tax benefit by $70 million in 2024 related to this matter and intends to defend itself vigorously.

Related Party Transactions

• The Utility declared common stock dividends of $575 million on February 20, May 22, and September 18, 2025, which were paid to PG&E Corporation on March 18, May 30, and September 26, 2025, respectively.

Stakeholder Impact

• **Shareholders**: Increased net income and EPS are positive, but ongoing wildfire liabilities and securities litigation pose risks to future returns. Dividend payments continue.
• **Customers**: Rate relief and cost recovery mechanisms, including the Wildfire Fund and the new Continuation Account (SB 254), are designed to spread costs, but high customer rates remain a risk factor. SB 254 includes a non-bypassable charge.
• **Employees**: The ability to attract and retain specialty personnel is identified as a risk, particularly for wildfire mitigation efforts.
• **Regulators (CPUC, FERC, OEIS, Cal Fire, USFS)**: The company is subject to extensive ongoing regulatory proceedings, investigations, and compliance requirements, with regulatory decisions significantly impacting financial results and operations.
• **Fire Victims**: Ongoing litigation and claims resolution processes for past wildfires continue, with the Fire Victim Trust addressing restitution for the 2018 Camp fire.
• **Creditors/Lenders**: Access to capital markets and credit facilities is crucial for financing capital requirements and liquidity needs. Credit ratings impact the cost and availability of borrowings.

Next Steps

• The Utility intends to update the CPUC and the OEIS based on its ongoing review of instances of noncompliance related to wildfire mitigation efforts.
• PG&E Corporation and the Utility expect to reduce their 20-year estimated life of the Wildfire Fund and assess the Wildfire Fund asset for accelerated amortization based on reliable, publicly available information, including when and if SCE accrues a liability or a Wildfire Fund receivable.
• The Utility expects to use the remaining net proceeds from the October 2, 2025, bond offerings for general corporate purposes after repaying a portion of its $1.9 billion 3.15% First Mortgage Bonds due January 1, 2026.
• PG&E Corporation and the Utility expect to begin accounting for the Continuation Account if the Wildfire Fund administrator determines that the Continuation Account is necessary and the CPUC approves the extension of non-bypassable charges to customers.
• The Utility expects to continue operating DCPP until its planned retirement.
• The Utility will adopt ASU No. 2023-09 in its Form 10-K for the year ending December 31, 2025.
• PG&E Corporation and the Utility are currently evaluating the impact of ASU No. 2024-03, ASU No. 2024-04, ASU No. 2025-05, ASU No. 2025-06, and ASU No. 2025-07 on their Condensed Consolidated Financial Statements and related disclosures.
• The Butte County Superior Court hearing on restitution for the 2018 Camp fire has been continued to November 14, 2025.
• The Utility expects to continue to prosecute omnibus objections with respect to certain Subordinated Claims in the Bankruptcy Court.
• The Utility is continuing its own investigation into the cause of the 2022 Mosquito fire.
• Individual claimant bellwether trial dates for the 2022 Mosquito fire are set for April 13, 2026.
• The Utility's petition for writ of mandate in the California First District Court of Appeal regarding Cal Fire's demurrer for the 2021 Dixie fire remains pending.
• The court set December 1, 2025, as the deadline for the plaintiffs to move for class certification for the 2021 Dixie fire putative class complaint.
• The Wildfire Fund administrator is required to prepare a report by April 1, 2026, that evaluates and sets forth recommendations on new models or approaches for mitigating natural catastrophes.
• The CPUC is considering revising the guidelines for the SB 884 10-Year Distribution Undergrounding Program, and the OEIS will issue separate compliance guidelines.
• A Proposed Decision (PD) for the 2027 GRC is expected by March 2027, with a final decision by May 2027.
• The CPUC scoping memo provides for a procedural schedule that would provide a final decision in 2025 for the 2026 Cost of Capital application.
• The Utility and California IOUs filed a petition for certiorari with the Supreme Court on October 7, 2025, regarding the FERC's denial of the 0.5% ROE adder for CAISO participation.
• The District Court granted motions to dismiss the third amended complaint for Wildfire-Related Securities Claims with leave to amend by October 30, 2025.
• PG&E Corporation intends to defend itself vigorously as to all costs in the IRS audit matter for tax years 2015-2018.
• Additional phases of construction for the in-situ groundwater treatment system at the Topock site will continue for several years.

Key Dates

Recommendation

While PG&E Corporation demonstrated improved financial performance in Q3 2025 with increased net income and operating cash flows, supported by favorable regulatory decisions on rate relief and cost recovery, significant uncertainties persist. The company faces substantial, multi-billion dollar liabilities from past wildfires, with ongoing litigation and investigations. The effectiveness and longevity of the Wildfire Fund and Continuation Account, along with the interpretation of new prudency standards, introduce considerable regulatory risk. Furthermore, delays in GRC proceedings and an ongoing IRS audit add to the uncertainty. The company's proactive capital financing and commitment to wildfire mitigation are positive, but the inherent risks associated with its operating environment and regulatory landscape warrant a cautious 'Hold' recommendation for a seasoned investor, awaiting clearer resolution on major liabilities and regulatory frameworks.

Keywords

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