AI interpretation based on checked source excerpts. Issuer assertions and evidence limitations remain explicit.
Policy quality-scores-2: six equally weighted categories. The overall score requires full coverage. Missing inputs are not zero. Qualitative grades are sourced interpretations, not probabilities. 6/6 · 18/10/2026
Moat63
Equal-weight average of four evidence-backed rubric grades (0–4), scaled to 100.
structural advantage · 3/4 · Operating transmission and distribution infrastructure, a substantial installed asset base and a required operating license demonstrate meaningful structural barriers. Exclusivity and comparative duplication costs are not disclosed.
durability · 2/4 · Installed infrastructure and regulated recovery support persistence, but license enforcement, uncertain recoveries and substantial financing requirements constrain confidence in durable shareholder returns.
customer dependency · 3/4 · A large gas customer base increased across 2023–2025 while residential usage per customer remained stable, supporting recurring dependence indirectly. Electricity alternatives limit the scope of that dependence; electric retention rates are unavailable.
erosion resilience · 2/4 · Reported wildfire and cost improvements show adaptation. Self-generation rate pressure, unrecovered mitigation spending and increasing Wildfire Fund expense demonstrate continuing vulnerabilities; prospective license sanctions are not treated as realized outcomes.
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 rose from $20.73 in 2023 to $24.39 in 2025, and electricity cost recovery increased in 2026. These are observed billing outcomes, but procurement costs, balancing accounts and reduced interim relief prevent attributing them to discretionary pricing power.
retention · 3/4 · Increasing gas customer counts and stable residential usage support strong recurring demand indirectly despite higher billed unit revenues. They do not establish individual renewal rates or isolate customer responses to pricing.
margin resilience · 2/4 · Actual electricity cost pass-through protects earnings from specified procurement increases, and first-half 2026 operating income improved. Broader protection is mixed because authorized recovery limits, wildfire expenses and cash-recovery timing remain material constraints.
contractual freedom · 1/4 · Cost-of-service ratemaking and changes in authorized interim relief establish limited freedom to set prices and recovery terms. Regulatory approval substitutes for unilateral pricing discretion.
Predictability63
Five consecutive 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
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, or reported pretax profit plus reported interest expense when operating income is unavailable. 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 or, if unavailable, EBIT calculated from reported pretax profit plus reported interest expense; 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. Nonpositive invested capital has no defined return and remains unavailable. 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 · Reported multi-year cost savings and a completed credit extension support discipline and financing execution. First-half operating cash flow of $3.639 billion fell below $6.159 billion of investing outflows, requiring external financing; debt issuance and modest share-count growth constrain the assessment. The evidence does not establish investment returns exceeding capital costs.
incentive alignment · 3/4 · Disclosed existing equity compensation, relative-TSR performance measures, anti-hedging rules and clawbacks demonstrate substantial alignment mechanisms. This assesses adopted structures rather than approval of the 2026 advisory proposal; complete ownership and realized payout evidence are missing.
execution · 3/4 · Reported ignition reductions, three consecutive years without major equipment-caused fires, completed undergrounding and four years of cost-target achievement support strong demonstrated execution. These are issuer-reported historical achievements, not proof that future wildfire risk or investment goals are resolved.
governance · 3/4 · Independent chairs, independent audit committees under written charters, actual wildfire oversight and clawback provisions establish substantive governance practices. They do not establish exceptional effectiveness or eliminate regulatory and operating 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.
Business / Electric Utility Operations · Filed 12/02/2026
33 PACIFIC GAS AND ELECTRIC COMPANY CONDENSED CONSOLIDATED BALANCE SHEETS (in millions) (Unaudited) Balance at June 30, 2026 December 31, 2025 ASSETS Current Assets Cash and cash equivalents $ 256 $ 353 Restricted cash and restricted cash equivalents (includes $215 million and $225 million related to VIEs at respective dates) 248 258 Accounts receivable Customers (net of allowance for doubtful accounts of $402 million and $408 million at respective dates) (includes $1.6 billion and $1.9 billion related to VIEs, net of allowance for doubtful accounts of $400 million and $408 million at respective dates) 1,884 2,267 Accrued unbilled revenue (includes $1.7 billion and $1.3 billion related to VIEs at respective dates) 1,909 1,463 Regulatory balancing accounts 5,380 6,300 Other (net of allowance for doubtful accounts of $19 million and $69 million at respective dates) 1,830 1,725 Regulatory assets 196 305 Inventories Gas stored underground and fuel oil 70 75 Materials and supplies 785 745 Wildfire Fund asset 291 297 Wildfire self-insurance asset 1,059 1,043 Other 804 643 Total current assets 14,712 15,474 Property, Plant, and Equipment Property, Plant, and Equipment 133,883 128,989 Construction work in progress 4,809 4,626 Financing lease ROU asset and other — 2 Total property, plant, and equipment 138,692 133,617 Accumulated depreciation (38,511) (37,269) Net property, plant, and equipment 100,181 96,348 Other Noncurrent Assets Regulatory assets 16,125 15,981 Customer credit trust 553 804 Nuclear decommissioning trusts 4,431 4,230 Operating lease ROU asset 481 445 Wildfire Fund asset 3,508 3,728 Other (includes noncurrent accounts receivable of $77 million and $67 million related to VIEs, net of noncurrent allowance for doubtful accounts of $19 million and $15 million at respective dates) 4,192 4,073 Total other noncurrent assets 29,290 29,261 TOTAL ASSETS $ 144,183 $ 141,083 See accompanying Notes to the Condensed Consolidated Financial Statements.
Utility condensed consolidated balance sheets / Property, Plant, and Equipment · Filed 23/07/2026
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).
Risk factors / Operating license and escalating enforcement mechanisms · 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.
MD&A / Cost-of-service ratemaking · Filed 23/07/2026
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.
Natural Gas Utility Operations / 2023–2025 customers, usage and billed revenues · 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.
Electric Utility Operations / Alternative electricity providers and self-generation · 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.
Competition / Self-generation and rate pressure · Filed 12/02/2026
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.
Liquidity / Wildfire costs, recovery timing and unrecovered mitigation spending · Filed 23/07/2026
The Utility’s cash flows were as follows: Six Months Ended June 30, (in millions) 2026 2025 Net cash provided by operating activities $ 3,639 $ 4,087 Net cash used in investing activities (6,159) (6,268) Net cash provided by financing activities 2,413 1,661 Net change in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (107) $ (520) Operating Activities The Utility’s cash flows from operating activities primarily consist of receipts from customers less payments of cash operating expenses.
Utility cash flows / First-half 2026 operating, investing and financing cash flows · Filed 23/07/2026
Their objective is to do so in an orderly manner to achieve a positive customer and community experience, while reducing natural gas system investments in targeted electrified communities.
Sustainability and resiliency / Targeted gas-system investment reductions · Filed 12/02/2026
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.
Operating revenues / Increased electricity cost recovery · Filed 23/07/2026
These costs are passed through to customers and do not impact net income.
Operating revenues / Customer pass-through and net-income treatment · Filed 23/07/2026
Partially offset by: •approximately $180 million less in interim rate relief authorized in the 2023 WMCE proceeding (see “2023 WMCE Application” below) in the three months ended June 30, 2026, compared to the same period in 2025.
Operating revenues / Reduced authorized interim rate relief · Filed 23/07/2026
CONDENSED CONSOLIDATED FINANCIAL STATEMENTS PG&E CORPORATION CONDENSED CONSOLIDATED STATEMENTS OF INCOME (in millions, except per share amounts) (Unaudited) Three Months Ended June 30, Six Months Ended June 30, 2026 2025 2026 2025 Operating Revenues Electric $ 4,388 $ 4,414 $ 9,355 $ 8,549 Natural gas 1,514 1,484 3,428 3,332 Total operating revenues 5,902 5,898 12,783 11,881 Operating Expenses Cost of electricity 800 599 1,361 998 Cost of natural gas 115 111 585 607 Operating and maintenance 2,536 2,860 5,648 5,506 Wildfire-related claims, net of recoveries — 50 — 99 Wildfire Fund expense 126 109 228 185 Depreciation, amortization, and decommissioning 1,062 1,073 2,228 2,170 Total operating expenses 4,639 4,802 10,050 9,565 Operating Income 1,263 1,096 2,733 2,316 Interest income 110 181 232 298 Interest expense (796) (792) (1,599) (1,526) Other income, net 97 84 213 154 Income Before Income Taxes 674 569 1,579 1,242 Income tax provision (benefit) (87) 20 (67) 59 Net Income 761 549 1,646 1,183 Preferred stock dividend requirement 28 28 55 55 Income Available for Common Shareholders $ 733 $ 521 $ 1,591 $ 1,128 Weighted Average Common Shares Outstanding, Basic 2,202 2,198 2,201 2,196 Weighted Average Common Shares Outstanding, Diluted 2,285 2,203 2,284 2,201 Net Income Per Common Share, Basic $ 0.33 $ 0.24 $ 0.72 $ 0.51 Net Income Per Common Share, Diluted $ 0.33 $ 0.24 $ 0.72 $ 0.51 See accompanying Notes to the Condensed Consolidated Financial Statements.
PG&E Corporation condensed consolidated statements of income / First-half 2026 results and share counts · Filed 23/07/2026
(in millions) Six Months Ended June 30, Cash provided by financing activities - 2025 $ 1,661 Net repayments under credit facilities (630) Net repayments under term loan (860) Proceeds from issuances of long-term debt, net of repayments 1,854 Dividend payments (100) Equity contributions from PG&E Corporation 522 Other financing activities (34) Net increase in cash provided by financing activities 752 Cash provided by financing activities - 2026 $ 2,413 Net cash provided by financing activities increased by $752 million, or 45%, during the six months ended June 30, 2026 as compared to the same period in 2025.
Liquidity / Actual debt financing, repayments and parent equity contributions · 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.
Debt / Utility revolving credit agreement extension and increased commitments · Filed 23/07/2026
•We reduced CPUC-reportable ignitions by over 40%, resulting in our third consecutive year with no major fires caused by our equipment.
Proxy opening letter / Reported ignition reduction and three-year major-fire record · Filed 09/04/2026
Consistent with our plan, we reduced non-fuel operating and maintenance (O&M) costs by 2.5% in 2025.
Proxy opening letter / Reported 2025 non-fuel O&M savings · 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.
Proxy opening letter / Reported four-year cost-target achievement and redeployment · Filed 09/04/2026
Since 2021 we have undergrounded over 1,200 miles.
Proxy / Completed undergrounding since 2021 · 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).
Share-based compensation / Performance-share settlement metrics · Filed 12/02/2026
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.
Compensation discussion / Actual 2025 target equity compensation mix · Filed 09/04/2026
Permit hedging or pledging | Our policy prohibits hedging and pledging of either company’s stock.
Compensation policies / Prohibition of hedging and pledging · 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.
Compensation policies / Adopted clawback and recoupment provisions · Filed 09/04/2026
Currently, each company has an independent Chair, so neither company has a lead independent director.
Governance / Independent chairs at both companies · 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.
Audit committee report / Independent directors 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.
Board oversight / Actual 2025 wildfire mitigation oversight · Filed 09/04/2026
During the six months ended June 30, 2026 and 2025, the Utility recorded amortization and accretion expense of $228 million and $185 million, respectively.
Wildfire Fund / Increased first-half amortization and accretion expense · Filed 23/07/2026
