AI interpretation based on checked source excerpts. Issuer assertions and evidence limitations remain explicit.
Policy quality-scores-3: six equally weighted categories. The overall score requires full coverage. Missing inputs are not zero. Qualitative grades are sourced interpretations, not probabilities. 6/6 · 31/10/2026
Moat63
Equal-weight average of four evidence-backed rubric grades (0–4), scaled to 100.
structural advantage · 3/4 · Operating transmission and distribution infrastructure and approximately 300 franchise agreements demonstrate substantial local infrastructure and access barriers. Most agreements have no expiration date. These contractual and operating facts support a strong structural advantage, although territorial exclusivity and the economic cost of competing network duplication are not disclosed.
durability · 2/4 · Indeterminate franchise terms and regulated recovery support persistence. However, operating rights can face enforcement, wildfire protections are conditional, and fund longevity is uncertain. The latest cash-flow statement also demonstrates continuing external financing needs. Durable infrastructure does not by itself establish durable excess shareholder returns.
customer dependency · 3/4 · Average gas customers increased from 4,605,628 in 2023 to 4,633,685 in 2025, while reported annual residential usage remained 37 Mcf. This indirectly supports strong recurring dependence on gas service infrastructure. Counts include alternative procurement customers, and electricity supply alternatives prevent extending this conclusion to exclusive bundled-energy dependence.
erosion resilience · 2/4 · Reported ignition reductions and repeated O&M target achievement demonstrate adaptation. Resilience remains mixed: self-generation creates rate pressure, mitigation spending has faced recovery delays, and actual costs were recorded for potential FERC disallowances. Conditional wildfire protections and uncertain fund longevity remain vulnerabilities rather than proof of inevitable deterioration.
Pricing power50
Equal-weight average of four evidence-backed rubric grades (0–4), scaled to 100.
realized pricing · 2/4 · Residential billed gas revenue per Mcf increased from $20.73 in 2023 to $24.39 in 2025. Second-quarter 2026 electricity cost-recovery revenue also increased by $201 million. These demonstrate observed billing outcomes, but procurement costs, balancing accounts and pass-through treatment prevent interpreting them as discretionary price increases or equivalent earnings gains.
retention · 3/4 · Growing average gas customer counts and stable reported residential usage across 2023–2025 demonstrate recurring service demand indirectly, alongside higher billed unit revenue. This supports strong infrastructure retention. It does not establish individual customer renewal rates or isolate price sensitivity, and the customer denominator includes users procuring gas elsewhere.
margin resilience · 2/4 · Disclosed electricity cost pass-through protects net income from specified procurement changes. Broader earnings protection is mixed: third-quarter GAAP earnings declined with lower authorized ROE and higher Wildfire Fund expense, partly offset by higher rate base and savings. Recorded potential-disallowance costs further demonstrate that recovery protection is incomplete.
contractual freedom · 1/4 · The CPUC authorizes recoverable revenue requirements, and cost-of-service earnings depend on managing spending within authorized amounts. The authorized CPUC ROE fell from 10.28% to 9.98%. These disclosures establish limited unilateral freedom over prices and investment recovery terms, despite meaningful regulated recovery mechanisms.
Predictability63
5 consecutive published annual periods. Equal weights: nondeclining revenue frequency; revenue-growth volatility (5–40pp); positive FCF frequency; FCF-margin volatility (3–20pp). Stability indicator, not a growth forecast.
- Nondeclining revenue years (%)
- 75.00
- Revenue growth volatility (pp)
- 4.81
- Positive FCF years (%)
- 0.00
- FCF margin volatility (pp)
- 7.12
- observedAnnualPeriods
- 5.00
Financial strength6
Equal-weight grades: debt/FCF (1–8x), net debt/earnings before interest and tax (0–5x), interest service (1–12x), current ratio (0.75–2x). Earnings use reported operating income, an original issuer-reported unadjusted EBIT reconciled to net income, income tax and signed net interest, or reported pretax profit plus reported gross interest expense. Reported EBIT is distinct from GAAP operating income and gross interest. Interest service uses earnings/interest expense; if unavailable, it uses reported operating cash flow/cash interest paid, without relabeling cash paid as accrued expense. Nonpositive cash flow/earnings score 0 for their service component; reported zero interest with a positive numerator scores 100. Net cash scores 100 for net leverage. Missing disclosures remain unavailable. General nonfinancial-company rubric, not a credit rating; exceptional and nonoperating gains are not normalized out. IFRS finance-cost and cash-flow classifications retain their reported scope.
- debtFcfGrade
- 0.00
- netDebtEbitGrade
- 0.00
- interestCoverageGrade
- 5.17
- currentRatioGrade
- 17.69
- Net debt / operating income (x)
- 12.67
- Interest coverage (x)
- 1.57
- Current ratio (x)
- 0.97
Capital allocation38
Three-year equal-weight indicators: pretax return on average invested capital (0–25%; equity + debt − cash, each year and its prior year), share-count growth (0–5%, lower better), share-based cost/revenue (2–20%, lower better), consolidated FCF/net income (0–1x). Return uses reported operating income, an original issuer-reported unadjusted EBIT reconciled to net income, income tax and signed net interest, or EBIT calculated from reported pretax profit plus reported gross interest expense; the issuer-reported EBIT is distinct from GAAP operating income and gross interest; exceptional/nonoperating gains are not normalized out. Share-based cost uses the reported cash-flow add-back or, if absent, separately reported recognized compensation expense; the latter never becomes an FCF adjustment. Nonpositive net income scores 0 for cash conversion; absent income/FCF stays unavailable. ROIC remains undefined for nonpositive invested capital; the explicit asset-return alternative does not change the ROIC chart. Missing financial inputs alone never trigger an alternative. Does not establish acquisition quality or buyback timing.
- 3-year pre-tax operating return (%)
- 4.68
- 3-year average dilution (%)
- 3.41
- 3-year average SBC / revenue (%)
- 0.44
- cashConversionGrade
- 0.00
Management69
Equal-weight average of four evidence-backed rubric grades (0–4), scaled to 100.
capital discipline · 2/4 · Repeated reported O&M target achievement and a completed credit extension support discipline. However, nine-month Utility operating cash flow of $6.262 billion trailed $9.296 billion of investing outflows, and potential-disallowance costs were recorded. O&M savings partly reflect capital-to-expense changes; superior investment returns and reduced total economic costs are not established.
incentive alignment · 3/4 · Existing equity compensation, three-year relative-TSR measures, ownership requirements, anti-hedging restrictions and clawbacks demonstrate substantial alignment mechanisms. All NEOs complied with ownership guidelines as of March 14, 2026, although eligible holdings include unvested RSUs. The later advisory approval confirms shareholder support, not realized payouts or exceptional alignment.
execution · 3/4 · Issuer-reported reductions of over 40% in CPUC-reportable ignitions, three consecutive years without major equipment-caused fires and four years exceeding non-fuel O&M targets support strong historical execution. Savings partly reflect capital-to-expense changes. These achievements do not establish that future wildfire exposure or investment-recovery risks have been resolved.
governance · 3/4 · Independent chairs, independent audit committees operating under written charters, adopted clawback provisions and actual 2025 wildfire-plan oversight establish substantive governance practices. These are disclosed structures and activities rather than assumptions about leadership reputation. The passages do not demonstrate exceptional effectiveness or elimination of regulatory and safety risks.
Evidence
Electric Utility Operations The Utility generates electricity and provides electric transmission and distribution services throughout its service area in northern and central California to residential, commercial, industrial, and agricultural customers.
2025 Form 10-K, filed 2026-02-12; Electric Utility Operations · Filed 12/02/2026
The Utility has franchise agreements with approximately 300 cities and counties that permit the Utility to install, operate, and maintain the Utility’s electric or natural gas facilities in the public streets and highways.
2025 Form 10-K, filed 2026-02-12; franchise agreements · Filed 12/02/2026
In most cases, the Utility’s franchise agreements are for an indeterminate term, with no expiration date.
2025 Form 10-K, filed 2026-02-12; franchise duration · Filed 12/02/2026
Higher steps of the process (steps 3 through 6) also contemplate additional enforcement mechanisms, including appointment of an independent third-party monitor, appointment of a chief restructuring officer, pursuit of the receivership remedy, and review of the Utility’s Certificate of Public Convenience and Necessity (i.e., its license to operate as a utility, which could be revoked).
2025 Form 10-K, filed 2026-02-12; regulatory enforcement and operating license · Filed 12/02/2026
2025
2024
2023
Customers (average for the year) (1)
4,633,685
4,614,080
4,605,628
Gas purchased (MMcf)
223,619
219,758
239,756
Average price of natural gas purchased (price per Mcf)
$
2.55
$
1.99
$
6.91
Bundled gas sales (MMcf):
Residential
147,827
146,842
171,889
Commercial
56,986
55,174
60,248
Total Bundled Gas Sales
$
204,813
$
202,016
$
232,137
Revenues (in millions):
Bundled gas sales:
Residential
$
3,651
$
3,089
$
3,686
Commercial
1,074
984
1,052
Other
101
159
(145)
Bundled gas revenues
4,826
4,232
4,593
Transportation service only revenue
1,937
1,815
1,603
Subtotal
6,763
6,047
6,196
Regulatory balancing accounts (2)
(146)
561
808
Total operating revenues
$
6,617
$
6,608
$
7,004
Selected Statistics:
Average annual residential usage (Mcf)
37
37
37
Average billed bundled gas sales revenues per Mcf:
Residential
$
24.39
$
20.74
$
20.73
Commercial
17.59
16.28
14.99
Net plant investment per customer
$
5,278
$
5,019
$
4,749
(1) These amounts include natural gas provided by core transport agents and CCAs that procure their own supplies of natural gas for their respective customers.
2025 Form 10-K, filed 2026-02-12; Natural Gas Utility Operations, 2025–2023 statistics and customer-count footnote · Filed 12/02/2026
(2) These amounts represent revenues authorized to be billed.
2025 Form 10-K, filed 2026-02-12; natural gas statistics, regulatory balancing accounts footnote · Filed 12/02/2026
Customers also can obtain electricity from alternative providers such as municipalities or CCAs, as well as from self-generation resources, such as rooftop solar installations.
2025 Form 10-K, filed 2026-02-12; competition and alternative electricity supply · Filed 12/02/2026
The levels of self-generation of electricity by customers (primarily solar installations) and customer enrollment in NEM, which allows self-generating customers employing qualifying renewable resources to receive bill credits at the full retail rate, put upward rate pressure on non-NEM customers.
2025 Form 10-K, filed 2026-02-12; self-generation and NEM rate pressure · Filed 12/02/2026
Under cost-of-service ratemaking, a utility’s earnings depend on its ability to manage costs within the amounts authorized for recovery in its ratemaking proceedings.
September 2026 Form 10-Q, filed 2026-10-22; cost-of-service ratemaking · Filed 22/10/2026
The CPUC authorizes the Utility’s capital structure, the aggregate amount of long-term and short-term debt that the Utility may issue, and the revenue requirements the Utility is able to collect to recover its cost of service.
September 2026 Form 10-Q, filed 2026-10-22; CPUC authorization of financing and revenue requirements · Filed 22/10/2026
The Utility’s cash flows were as follows:
Nine Months Ended September 30,
(in millions)
2026
2025
Net cash provided by operating activities
$
6,262
$
7,019
Net cash used in investing activities
(9,296)
(9,250)
Net cash provided by financing activities
3,166
1,874
Net change in cash, cash equivalents, restricted cash, and restricted cash equivalents
$
132
$
(357)
Operating Activities
The Utility’s cash flows from operating activities primarily consist of receipts from customers less payments of cash operating expenses.
September 2026 Form 10-Q, filed 2026-10-22; Utility cash flows, nine months ended September 30, 2026 and 2025, in millions · Filed 22/10/2026
Future cash flow from operating activities will be affected by various factors, including: •the timing and amount of costs in connection with the 2019 Kincade fire, the 2021 Dixie fire, and the 2022 Mosquito fire and the timing and amount of any potential related insurance, Wildfire Fund, and regulatory recoveries; •the timing and amount of costs in connection with future wildfires and the timing and amount of any potential related insurance, including funds available from self-insurance and the Wildfire Fund (see “Wildfire Fund Recoveries under AB 1054 and SB 254” in Note 10 of the Notes to the Condensed Consolidated Financial Statements in Part I, Item 1); •the timing and amount of costs in connection with the portion of the 2023-2025 WMP that are being recovered through rates and the portion of the costs previously incurred in connection with the 2021-2022 WMP that are not currently being recovered through rates (see “Regulatory Matters” below for more information); •the timing and outcomes of the Utility’s pending and future ratemaking and regulatory proceedings, including the extent to which PG&E Corporation and the Utility are able to recover their costs through regulated rates as recorded in memorandum accounts or balancing accounts, or as otherwise requested; and •the timing and amount of electric and natural gas commodity price volatility and differences between commodity costs and revenue collections.
June 2026 Form 10-Q, filed 2026-07-23; operating cash-flow recovery timing and unrecovered mitigation costs · Filed 23/07/2026
This increase was primarily due to: •$201 million more in revenues to recover the cost of electricity in the three months ended June 30, 2026, compared to the same period in 2025.
June 2026 Form 10-Q, filed 2026-07-23; electricity cost-recovery revenue change, three months ended June 30 · Filed 23/07/2026
These costs are passed through to customers and do not impact net income.
June 2026 Form 10-Q, filed 2026-07-23; net-income treatment of electricity cost pass-through · Filed 23/07/2026
2. Year-over-year changes in customer capital investment were primarily due to the earnings impact of higher rate base, the 2023 WMCE final decision, partially offset by the change in the Utility’s authorized CPUC return on equity from 10.28% to 9.98%.
Third-quarter earnings presentation, filed 2026-10-22; earnings-driver endnote and authorized CPUC return on equity · Filed 22/10/2026
The decrease in GAAP earnings was primarily driven by lower CPUC return on equity in effect during 2026 as compared to 2025, the one-time catch-up impacts of the tax methodology change implemented in 2025, and increased Wildfire Fund expense, partially offset by increased customer capital investment due to the earnings on higher rate base and net O&M savings.
Third-quarter earnings release, filed 2026-10-22; explanation of third-quarter 2026 GAAP earnings decrease · Filed 22/10/2026
(6) The Utility recorded costs of $1 million (before the tax impact of $0 million) and $70 million (before the tax impact of $20 million) during the three and nine months ended September 30, 2026, respectively, related to an adjustment for potential disallowances associated with a FERC TO20 settlement.
Third-quarter earnings release, filed 2026-10-22; reconciliation footnote 6, costs recorded for potential FERC TO20 disallowances · Filed 22/10/2026
•We reduced CPUC-reportable ignitions by over 40%, resulting in our third consecutive year with no major fires caused by our equipment.
2026 joint proxy, filed 2026-04-09; shareholder letter reporting 2025 ignition and major-fire outcomes · Filed 09/04/2026
Consistent with our plan, we reduced non-fuel operating and maintenance (O&M) costs by 2.5% in 2025.
2026 joint proxy, filed 2026-04-09; reported 2025 non-fuel O&M cost reduction · Filed 09/04/2026
In fact, we’ve exceeded our non-fuel O&M targets for four years in a row, allowing us to redeploy over $700 million for the benefit of customers.
2026 joint proxy, filed 2026-04-09; reported four-year O&M target achievement and redeployment · Filed 09/04/2026
(3) Represents Operating and maintenance savings primarily driven by an improvement in the capital to expense ratio, driving lower operating expenses during the three and six months ended June 30, 2026.
Second-quarter earnings presentation, filed 2026-07-23; earnings-driver footnote 3, capital-to-expense contribution to O&M savings · Filed 23/07/2026
Utility On June 22, 2026, the Utility amended its existing revolving credit agreement to, among other things, (i) extend the maturity date of such agreement to June 20, 2031, (ii) increase the aggregate commitments from $5.4 billion to $6.25 billion and (iii) modify both the interest rate pricing grid and commitment fee pricing grid.
June 2026 Form 10-Q, filed 2026-07-23; completed June 22, 2026 revolving credit amendment · Filed 23/07/2026
Align with shareholders • Annual equity-based compensation, the value of which reflects movements in our stock price, accounted for more than 77% of Corporation CEO target compensation and an average of approximately 52% for other NEOs in 2025.
2026 joint proxy, filed 2026-04-09; equity-based share of 2025 target compensation · Filed 09/04/2026
Following vesting, performance shares are settled in shares of common stock based on either PG&E Corporation’s total shareholder return relative to a specified group of industry peer companies over a three-year performance period (“TSR”) or an internal PG&E Corporation metric (subject in some instances to a multiplier based on TSR).
2025 Form 10-K, filed 2026-02-12; performance-share settlement measures and three-year relative TSR · Filed 12/02/2026
In 2025, the Committee granted a temporary exception to one NEO to transfer shares; however, as of March 14, 2026, all NEOs are in compliance with the guidelines.
2026 joint proxy, filed 2026-04-09; 2025 ownership-guideline exception and compliance as of March 14, 2026 · Filed 09/04/2026
Covered individuals may not engage in short sales, transactions in publicly traded options, or hedging or monetization transactions; hold securities in a margin account; or pledge securities as collateral for a loan.
2026 joint proxy, filed 2026-04-09; prohibited hedging, monetization, margin and pledging activities · Filed 09/04/2026
Operate clawback provisions | All incentive compensation and severance for certain officers is subject to clawback or recoupment, with provisions beyond those required by the listing exchange.
2026 joint proxy, filed 2026-04-09; adopted clawback and recoupment provisions · Filed 09/04/2026
At both the Corporation and the Utility, the Chair of the Board is independent.
2026 joint proxy, filed 2026-04-09; independent chairs at Corporation and Utility · Filed 09/04/2026
Report of the Audit Committees
The Audit Committees of PG&E Corporation and Pacific Gas and Electric Company are comprised of independent directors and operate under written charters adopted by their respective Boards.
2026 joint proxy, filed 2026-04-09; independent audit committees and written charters · Filed 09/04/2026
In 2025, the Safety and Nuclear Oversight Committees continued to receive regular updates on the execution of the WMP, to engage with senior leadership, and to report out to the Boards on progress regularly.
2026 joint proxy, filed 2026-04-09; actual 2025 wildfire-plan oversight · Filed 09/04/2026
The disallowance cap, which caps the amount of liability that the Utility could be required to bear for a catastrophic wildfire, is inapplicable if the Wildfire Fund administrator determines that the electric utility company’s actions or inactions that resulted in the applicable wildfire constituted “conscious or willful disregard for the rights and safety of others,” or the electric utility company fails to maintain a valid safety certification at the time the applicable wildfire ignited.
2025 Form 10-K, filed 2026-02-12; exceptions to wildfire disallowance cap · Filed 12/02/2026
The estimated life of the fund has a high degree of uncertainty for many of these assumptions, and so subsequent changes could materially impact the remaining estimated life of the fund.
September 2026 Form 10-Q, filed 2026-10-22; uncertainty in estimated Wildfire Fund life · Filed 22/10/2026
2. Non-binding advisory vote to approve the company’s executive compensation
Annual-meeting results Form 8-K, filed 2026-05-26; PG&E Corporation executive-compensation advisory-vote identification · Filed 26/05/2026
(included as Proposal 2 in the proxy statement):
For:
1,670,209,325
Against:
168,851,135
Abstain:
12,443,857
Broker Non-Vote(1)
94,215,653
(1)
See footnote 1 above.
Annual-meeting results Form 8-K, filed 2026-05-26; PG&E Corporation Proposal 2 voting results · Filed 26/05/2026
This
proposal was approved.
3. Ratification of the appointment of Deloitte & Touche LLP as the independent
Annual-meeting results Form 8-K, filed 2026-05-26; PG&E Corporation Proposal 2 approval · Filed 26/05/2026
Compliance with the ownership target includes beneficially owned stock, phantom stock units credited to the Supplemental Retirement Savings Plan, stock held in the stock fund of any defined contribution plan sponsored by either Company or its subsidiaries, and unvested RSUs.
2026 joint proxy, filed 2026-04-09; holdings counted toward executive ownership targets · Filed 09/04/2026
Our guidelines require all officers to achieve and maintain a minimum investment in PG&E Corporation common stock, expressed as a multiple of their base salary.
2026 joint proxy, filed 2026-04-09; executive minimum stock-investment requirements · Filed 09/04/2026
