Summary of Significant Accounting Policies

12 Months Ended

Dec. 31, 2023

Summary of Significant Accounting Policies

Summary of Significant Accounting Policies

Note 1.Summary of Significant Accounting Policies

Organization and Basis of Presentation

Edison International is the ultimate parent holding company of Southern California Edison Company ("SCE") and Edison Energy, LLC ("Edison Energy"). SCE is an investor-owned public utility primarily engaged in the business of supplying and delivering electricity to an approximately 50,000 square mile area of Southern California. Edison Energy is a global energy advisory firm providing integrated sustainability and energy solutions to commercial, industrial and institutional customers. Edison Energy's business activities are currently not material to report as a separate business segment. These combined notes to the consolidated financial statements apply to both Edison International and SCE unless otherwise described. Edison International's consolidated financial statements include the accounts of Edison International, SCE, and other controlled subsidiaries. References to Edison International refer to the consolidated group of Edison International and its subsidiaries. References to "Edison International Parent and Other" refer to Edison International Parent and its competitive subsidiaries and "Edison International Parent" refer to Edison International on a stand-alone basis, not consolidated with its subsidiaries. SCE's consolidated financial statements include the accounts of SCE, its controlled subsidiaries and a variable interest entity, SCE Recovery Funding LLC, of which SCE is the primary beneficiary. All intercompany transactions have been eliminated from the consolidated financial statements.

Edison International's and SCE's accounting policies conform to accounting principles generally accepted in the United States of America ("GAAP"), including the accounting principles for rate-regulated enterprises, which reflect the ratemaking policies of the California Public Utility Commission ("CPUC") and the Federal Energy Regulatory Commission ("FERC"). SCE applies authoritative guidance for rate-regulated enterprises to the portion of its operations in which regulators set rates at levels intended to recover the estimated costs of providing service, plus a return on net investments in assets, or rate base. Regulators may also impose certain penalties or grant certain incentives. Due to timing and other differences in the collection of electric utility revenue, these accounting principles require an incurred cost that would otherwise be charged to expense by a non-regulated entity to be capitalized as a regulatory asset if it is probable that the cost is recoverable through future rates; and conversely the accounting principles require recording of a regulatory liability for amounts collected in rates to recover costs expected to be incurred in the future or amounts collected in excess of costs incurred and refundable to customers. In addition, SCE recognizes revenue and regulatory assets from alternative revenue programs, which enables the utility to adjust future rates in response to past activities or completed events, if certain criteria are met. SCE assesses, at the end of each reporting period, whether regulatory assets are probable of future recovery. See Note 11 for composition of regulatory assets and liabilities.

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reported period. Actual results could differ from those estimates. Certain prior year amounts have been conformed to the current year's presentation, including the separate presentation of derivative assets and liabilities on Edison International's and SCE's consolidated statements of cash flows and the aggregation of significant components in the net regulatory balancing and memorandum accounts table in Note 11.

Cash, Cash Equivalents and Restricted Cash

Cash equivalents consist of investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of three months or less. The cash equivalents were as follows:

	Edison International				SCE
	December 31,
(in millions)	2023		2022		2023		2022
Money market funds	$	199	$	784	$	78	$	647

Cash is temporarily invested until required for check clearing. Checks issued, but not yet paid by the financial institution, are reclassified from cash to accounts payable at the end of each reporting period.

The following table sets forth the cash, cash equivalents and restricted cash included in the consolidated statements of cash flows:

	December 31,
(in millions)	2023		2022
Edison International:
Cash and cash equivalents	$	345	$	914
Short-term restricted cash1		35		3
Long-term restricted cash2		152		—
Total cash, cash equivalents and restricted cash	$	532	$	917
SCE:
Cash and cash equivalents	$	214	$	766
Short-term restricted cash1		33		—
Long-term restricted cash2		151		—
Total cash, cash equivalents and restricted cash	$	398	$	766

1 Includes SCE Recovery Funding LLC's restricted cash for payments of senior secured recovery bonds and is reflected in "Other current assets" on Edison International's and SCE's consolidated balance sheets.

2 The SCE amount represents cash collected for customer-funded wildfire self-insurance and is reflected in "Other long-term assets" on Edison International's and SCE's consolidated balance sheets. See Note 12 for further information.

Allowance for Uncollectible Accounts

The allowance for uncollectible accounts is recorded based on SCE's estimate of expected credit losses and adjusted over the life of the receivables as needed. Since the customer base of SCE is concentrated in Southern California and exposes SCE to a homogeneous set of economic conditions, the allowance is measured on a collective basis on the historical amounts written-off, assessment of customer collectibility and current economic trends, including unemployment rates and any likelihood of recession for the region.

The following table sets forth the changes in allowance for uncollectible accounts for SCE:

(in millions)	Customers		All others		Total
Balance at December 31, 2020	$	175	$	13	$	188
Current period provision for uncollectible accounts1		124		11		135
Write-offs, net of recoveries		(6)		(8)		(14)
Balance at December 31, 2021	$	293	$	16	$	309
Current period provision for uncollectible accounts1		111		11		122
Write-offs, net of recoveries		(70)		(7)		(77)
Balance at December 31, 2022²	$	334	$	20	$	354
Current period provision for uncollectible accounts1		109		6		115
Write-offs, net of recoveries		(96)		(9)		(105)
Balance at December 31, 2023²	$	347	$	17	$	364

1 This includes $78 million, $40 million and $91 million of incremental costs for the years ended December 31, 2023, 2022 and 2021, respectively, which were probable of recovery from customers and recorded as regulatory assets.

2 Approximately $4 million and $7 million of allowance for uncollectible accounts are included in "Other long-term assets" on SCE's consolidated balance sheets as of December 31, 2023 and December 31, 2022, respectively.

Inventory

SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at weighted average cost.

Edison Carrier Solutions

SCE operates commercial telecommunications service under the name of Edison Carrier Solutions ("ECS"), leveraging the temporarily available capacity of SCE's telecommunications network. As technology evolves, management is implementing strategic shifts in ECS services, including potential disposition of assets and ceasing to offer certain wire data services. ECS has notified affected customers of its intent to discontinue certain services over time and gave customers the option to discontinue those services. As a result of customer cancellations in the second quarter of 2023, materials and supplies inventory supporting data services are expected to be sold instead of placed into service and have been written-down to net realizable value, resulting in a charge of $13 million ($9 million after-tax). Labor and other costs of $4 million previously recorded as construction work in progress for projects no longer probable of completion were also expensed in the period.

Emission Allowances and Energy Credits

SCE is allocated greenhouse gas ("GHG") allowances annually which it is then required to sell into quarterly auctions. GHG proceeds from the auctions are recorded as a regulatory liability to be refunded to customers. SCE purchases GHG allowances in quarterly auctions or from counterparties to satisfy its GHG emission compliance obligations and recovers such costs of GHG allowances from customers. GHG allowances held for use are classified as "Other current assets" on the consolidated balance sheets and are stated, similar to an inventory method, at the lower of weighted average cost or market. SCE will evaluate GHG allowances for impairment upon a triggering event that would indicate SCE might not recover the full cost of an allowance. SCE had GHG allowances held for use of $128 million and $87 million at December 31, 2023 and 2022, respectively. GHG emission obligations were $117 million and $55 million at December 31, 2023 and 2022, respectively, and are classified as "Other current liabilities" on the consolidated balance sheets.

SCE is allocated low carbon fuel standard ("LCFS") credits which it sells to market participants. Proceeds from the sales, net of selling fees and program administration expenses, are recorded in a balancing account to be refunded to eligible

customers. SCE's net proceeds from the sale of these LCFS credits were $248 million and $218 million and are classified as "Regulatory liabilities" on the consolidated balance sheets at December 31, 2023 and 2022, respectively.

Property, Plant and Equipment

SCE plant additions, including replacements and betterments, are capitalized. Direct material and labor and indirect costs such as construction overhead, administrative and general costs, employee benefits, and property taxes are capitalized as part of plant additions. The CPUC authorizes a capitalization rate for each of the indirect costs which are allocated to each project based on either labor or total costs.

Estimated useful lives authorized by the CPUC in the 2021 General Rate Case ("GRC") and weighted average useful lives of SCE's property, plant and equipment, are as follows:

		Weighted Average
	Estimated Useful Lives	Useful Lives
Generation plant	10 years to 54 years	39 years
Distribution plant	20 years to 67 years	50 years
Transmission plant	30 years to 65 years	54 years
General plant and other	5 years to 60 years	20 years

Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. SCE's depreciation expense was $2.5 billion, $2.5 billion and $2.0 billion for 2023, 2022 and 2021, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 4.1%, 4.2% and 3.7% for 2023, 2022 and 2021, respectively. The original costs of retired property are charged to accumulated depreciation. See Note 2 for further information.

Nuclear fuel for the Palo Verde Nuclear Generating Station ("Palo Verde") is recorded as utility plant (nuclear fuel in the fabrication and installation phase is recorded as construction in progress) in accordance with CPUC ratemaking procedures. Palo Verde nuclear fuel is amortized using the units of production method.

Allowance for funds used during construction ("AFUDC") represents the estimated cost of debt and equity funds that finance utility-plant construction and is capitalized during certain plant construction. AFUDC is recovered in rates through depreciation expense over the useful life of the related asset. AFUDC equity represents a method to compensate SCE for the estimated cost of equity used to finance utility plant additions and is recorded as part of construction in progress. AFUDC equity was $157 million, $137 million and $118 million in 2023, 2022 and 2021, respectively, and is reflected in "Other income" on the consolidated statements of income. AFUDC debt was $74 million, $53 million and $50 million in 2023, 2022 and 2021, respectively and is reflected as a reduction of "Interest expense" on the consolidated statements of income.

Major Maintenance

Major maintenance costs for SCE's facilities and equipment are expensed as incurred.

Impairment of Long-Lived Assets

Impairments of long-lived assets are evaluated based on a review of estimated future cash flows expected to be generated whenever events or changes in circumstances indicate that the carrying amount of such investments or assets may not be recoverable. If the carrying amount of a long-lived asset exceeds expected future cash flows, undiscounted and without interest charges, an impairment loss is recognized in the amount of the excess of fair value over the carrying amount. Fair value is determined via market, cost and income-based valuation techniques, as appropriate.

Accounting principles for rate-regulated enterprises also require recognition of an impairment loss if it becomes probable that the regulated utility will abandon a plant investment, or if it becomes probable that the cost of a recently completed plant will be disallowed, either directly or indirectly, for ratemaking purposes and a reasonable estimate of the disallowance amount can be made.

In September 2022, the CPUC approved the settlement agreement between SCE and The Utility Reform Network for SCE's Customer Service Re-platform proceeding filed in 2021 for expenditures incurred through April 2021. As a result of the settlement agreement, SCE recorded a $47 million ($34 million after-tax) impairment of property, plant and equipment, reflected in "Impairment, net of other operating income" in the consolidated statements of income.

In August 2021, as a result of adoption of the 2021 GRC, SCE recorded $79 million ($47 million after-tax) in impairment charges related to disallowed capital expenditures of pole replacements the CPUC determined were performed prematurely in 2021. The impairment is included in "Impairment, net of other operating income" in the consolidated statements of income.

Initial and annual contributions to the wildfire insurance fund established pursuant to California Assembly Bill 1054 (the "Wildfire Insurance Fund" and "AB 1054")

Edison International and SCE accounted for the contributions to the Wildfire Insurance Fund similarly to prepaid insurance. No period of coverage was provided in AB 1054, therefore expense is being allocated to periods ratably based on an estimated period of coverage. At December 31, 2023 and 2022, Edison International and SCE had a $2.0 billion and a $2.2 billion long-term asset, respectively, as well as a $204 million current asset for both years, reflected as "Wildfire Insurance Fund contributions" in their consolidated balance sheets for the initial $2.4 billion contribution made during 2019 and the present value of annual contributions SCE committed to make to the Wildfire Insurance Fund, reduced by amortization. At December 31, 2023 and 2022, long-term liabilities of $450 million and $536 million, respectively, have been reflected in "Other deferred credits and other long-term liabilities" for the present value of unpaid contributions. Contributions were discounted to the present value using US treasury interest rates at the date SCE committed to participate in the Wildfire Insurance Fund.

In 2023 and 2022, the asset was amortized based on an estimated period of coverage of 15 years. All expenses related to the contributions are being reflected in "Wildfire Insurance Fund Expense" in the consolidated statements of income. Changes in the estimated period of coverage provided by the Wildfire Insurance Fund could lead to material changes in future expense recognition. In estimating the period of coverage, Edison International and SCE used Monte Carlo simulations based on historical data from wildfires caused by electrical utility equipment to estimate expected losses, using nine years (2014 – 2022) of available historical data in 2023 and eight years (2014 – 2021) of available historical data in 2022. The details of the operation of the Wildfire Insurance Fund and estimates related to claims by SCE, Pacific Gas & Electric Company ("PG&E"), and San Diego Gas & Electric ("SDG&E") against the fund have been applied to the expected loss simulations to estimate the period of coverage of the fund. The most sensitive inputs to the estimated period of coverage are the expected frequency of wildfire events caused by investor-owned utility electrical equipment and the estimated costs associated with those forecasted events. Edison International and SCE reassesses the period of coverage of the fund at least annually in January each year, or upon claims being made from the fund for catastrophic wildfires. Based on information available in January of 2024 regarding catastrophic wildfires during 2023, SCE reassessed its estimate of the life of the Wildfire Insurance Fund. After incorporating 2023 expected losses into the historical data for the Monte Carlo simulations by using ten years of historical data (2014 – 2023), SCE determined that effective in the first quarter of 2024, the life of the Wildfire Insurance Fund is expected to increase to 20 years from the date SCE committed to participate in the Wildfire Insurance Fund.

Edison International and SCE will assess the Wildfire Insurance Fund contribution assets for impairment in the event that a participating utility's electrical equipment is found to be the substantial cause of a catastrophic wildfire, based on

the ability of SCE to benefit from the coverage provided by the Wildfire Insurance Fund in an amount equal to the recorded assets.

Nuclear Decommissioning and Asset Retirement Obligations

The fair value of a liability for an asset retirement obligation ("ARO") is recorded in the period in which it is incurred, including a liability for the fair value of a conditional ARO, if the fair value can be reasonably estimated even though uncertainty exists about the timing and/or method of settlement. When an ARO liability is initially recorded, SCE capitalizes the cost by increasing the carrying amount of the related long-lived asset. For each subsequent period, the liability is increased for accretion expense and the capitalized cost is depreciated over the useful life of the related asset.

SCE has not recorded an ARO for assets that are expected to operate indefinitely or where SCE cannot estimate a settlement date (or range of potential settlement dates). As such, ARO liabilities are not recorded for certain retirement activities, including certain hydroelectric facilities.

The following table summarizes the changes in SCE's ARO liability:

	December 31,
(in millions)	2023		2022
Beginning balance	$	2,754	$	2,772
Accretion1		144		143
Revisions		(3)		28
Liabilities settled		(229)		(189)
Ending balance	$	2,666	$	2,754

1 An ARO represents the present value of a future obligation. Accretion is an increase in the liability to account for the time value of money resulting from discounting.

AROs related to decommissioning of SCE's nuclear power facilities are based on site-specific studies conducted as part of each Nuclear Decommissioning Cost Triennial Proceeding ("NDCTP") conducted before the CPUC. Revisions of an ARO are established for updated site-specific decommissioning cost estimates.

The ARO for decommissioning SCE's San Onofre Nuclear Generating Station ("San Onofre") and Palo Verde nuclear power facilities is $2.2 billion as of December 31, 2023. The liability to decommission SCE's nuclear power facilities is based on a 2020 decommissioning study, filed as part of the 2021 NDCTP, for San Onofre Unit 1, 2 and 3 and a 2019 decommissioning study for Palo Verde, with revisions to the cost estimate in 2020.

SCE records an ARO regulatory liability as a result of timing differences between the recognition of costs and the recovery of costs through the ratemaking process. For further information, see Note 11.

Decommissioning of San Onofre Unit 1 began in 1999 and the transfer of spent nuclear fuel from Unit 1 to dry cask storage in the Independent Spent Fuel Storage Installation ("ISFSI") 1 was completed in 2005. Major decommissioning work for Unit 1 has been completed except for certain underground work.

Decommissioning of San Onofre Units 2 and 3 began in June 2013 and the transfer of spent nuclear fuel from San Onofre Units 2 and 3 to dry cask storage in the two ISFSIs was completed in August 2020. In August 2020, SCE commenced, and is currently conducting, major decommissioning activities in accordance with the terms of the Coastal Developmental Permit for San Onofre Units 2 and 3.

Decommissioning costs, which are recovered through customer rates over the term of each nuclear facility's operating license, are recorded as a component of depreciation expense, with a corresponding credit to the ARO regulatory liability. Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. Amortization of the ARO asset (included within the

unamortized nuclear investment) and accretion of the ARO liability are deferred as decreases to the ARO regulatory liability account, resulting in no impact on earnings.

SCE has collected in rates amounts for the future decommissioning of its nuclear assets and has placed those amounts in independent trusts. Amounts collected in rates in excess of the ARO liability are classified as regulatory liabilities.

Changes in the estimated costs, timing of decommissioning or the assumptions underlying these estimates could cause material revisions to the estimated total cost to decommission. SCE currently estimates that it will spend approximately $6.1 billion through 2080 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 2.2% to 7.5% (depending on the cost element) annually. These costs are expected to be funded from independent decommissioning trusts. SCE estimates annual after-tax earnings on the decommissioning funds of 3.1% to 6.1% dependent on asset class. If the assumed return on trust assets is not earned or costs escalate at higher rates, SCE expects that additional funds needed for decommissioning will be recoverable through future rates, subject to a reasonableness review. See Note 10 for further information.

Due to regulatory recovery of SCE's nuclear decommissioning expense, prudently incurred costs for nuclear decommissioning activities do not affect SCE's earnings. SCE's nuclear decommissioning costs are subject to CPUC review through the triennial regulatory proceedings. SCE's nuclear decommissioning trust investments primarily consist of fixed income investments that are classified as available-for-sale and equity investments. Due to regulatory mechanisms, investment earnings and realized gains and losses have no impact on earnings. Unrealized gains and losses on decommissioning trust funds, including impairment, increase or decrease the trust assets and the related regulatory asset or liability and have no impact on electric utility revenue or decommissioning expense. SCE reviews each fixed income security for impairment on the last day of each month. If the fair value on the last day of the month is less than the amortized cost for that security, SCE impairs the disclosed amortized cost. If the fair value is greater or less than the carrying value for that security at the time of sale, SCE recognizes a related realized gain or loss, respectively.

Deferred Financing Costs

Debt premium, discount and issuance expenses incurred in connection with obtaining financing are deferred and amortized over the life of each debt issue. These deferred amounts are recorded as an offset to long-term debt. See Note 5 for further details. Under CPUC ratemaking procedures, SCE's debt reacquisition expenses are amortized over the remaining life of the reacquired debt, or if refinanced, the life of the new debt. The unamortized losses on reacquired debt are reflected as long-term "Regulatory assets" in the consolidated balance sheets. See Note 11 for further details.

Amortization of deferred financing costs charged to interest expense is as follows:

	Edison International						SCE
	Years ended December 31,
(in millions)	2023		2022		2021		2023		2022		2021
Amortization of deferred financing costs charged to interest expense	$	39	$	37	$	34	$	32	$	31	$	29

Revenue Recognition

Revenue is recognized by Edison International and SCE when a performance obligation to transfer control of the promised goods is satisfied or when services are rendered to customers. This typically occurs when electricity is delivered to customers, which includes amounts for services rendered but unbilled at the end of a reporting period.

SCE's Revenue from Contracts with Customers

Provision of Electricity

SCE principally generates revenue through supplying and delivering electricity to its customers. Rates charged to customers are based on tariff rates, approved by the CPUC and FERC. Starting with SCE's 2021 GRC, revenue is authorized through quadrennial GRC proceedings, which are intended to provide SCE a reasonable opportunity to recover its costs and earn a return on its CPUC-jurisdictional rate base. The CPUC sets an annual revenue requirement for the base year and the remaining three years are set by a methodology established in the GRC proceeding. As described above, SCE also earns revenue, with no return, to recover costs for power procurement, certain wildfire related expenses and other activities.

Revenue is authorized by the FERC through a formula rate which is intended to provide SCE a reasonable opportunity to recover transmission capital and operating costs that are prudently incurred, including a return on its FERC-jurisdictional rate base. Under the operation of the formula rate, transmission revenue is updated to actual cost of service annually.

For SCE's electricity sales for both residential and non-residential customers, SCE satisfies the performance obligation of delivering electricity over time as the customers simultaneously receive and consume the delivered electricity.

Energy sales are typically on a month-to-month implied contract for transmission, distribution and generation services. Revenue is recognized over time as the energy is supplied and delivered to customers and the respective revenue is billed and paid on a monthly basis.

CPUC and FERC rates decouple authorized revenue from the volume of electricity sales and the price of energy procured so that SCE receives revenue equal to amounts authorized by the relevant regulatory agencies. As a result, the volume of electricity sold to customers and specific customer classes does not have a direct impact on SCE's financial results. See Note 7 for further information on SCE's revenue.

Sales and Use Taxes

SCE bills certain sales and use taxes levied by state or local governments to its customers. Included in these sales and use taxes are franchise fees, which SCE pays to various municipalities (based on contracts with these municipalities) in order to operate within the limits of the municipality. SCE bills these franchise fees to its customers based on a CPUC-authorized rate. These franchise fees, which are required to be paid regardless of SCE's ability to collect from the customer, are accounted for on a gross basis. SCE's franchise fees billed to customers were $168 million, $172 million and $147 million for the years ended December 31, 2023, 2022 and 2021, respectively. When SCE acts as an agent for sales and use tax, the taxes are accounted for on a net basis. Amounts billed to and collected from customers for these taxes are remitted to the taxing authorities and are not recognized as electric utility revenue.

SCE's Alternative Revenue Programs

The CPUC and FERC have authorized additional, alternative revenue programs which adjust billings for the effects of broad external factors or provide for additional billings if the utility achieves certain objectives. These alternative revenue programs allow SCE to recover costs that SCE has been authorized to pass on to customers, including costs of certain capital and operations and maintenance activities, costs to purchase electricity and natural gas, and to fund public purpose, demand response, and customer energy efficiency programs, and earn a reasonable return. In general, revenue is recognized for these alternative revenue programs at the time the costs are incurred, or at the time when specific events permitting billing of the additional revenues have been completed. SCE begins recognizing revenues for these programs when a program has been established by an order from either the CPUC or FERC that allows for automatic adjustment of future rates, the amount of revenue for the period is objectively determinable and probable of recovery and the revenue will be collected within 24 months following the end of the annual period.

Power Purchase Agreements

SCE enters into power purchase agreements ("PPAs") in the normal course of business. A power purchase agreement may be considered a variable interest in a variable interest entity ("VIE"). If SCE is the primary beneficiary in the VIE, SCE is required to consolidate the VIE. None of SCE's PPAs resulted in consolidation at December 31, 2023 and 2022. See Note 3 for further discussion of PPAs that are considered variable interests.

A PPA may also contain a lease for accounting purposes. See "Leases" below and Note 12 and Note 13 for further discussion of SCE's PPAs. A PPA that does not contain a lease may be classified as a derivative which is recorded at fair value on the consolidated balance sheets, unless the PPA is eligible for an election to designate as a normal purchase or sale, which is accounted for on an accrual basis as an executory contract.

PPAs that do not meet the above classifications are accounted for on an accrual basis.

Derivative Instruments

SCE records derivative instruments on its consolidated balance sheets as either assets or liabilities measured at fair value unless otherwise exempted from derivative treatment as normal purchases or sales. The normal purchases and sales exception requires, among other things, physical delivery in quantities expected to be used or sold over a reasonable period in the normal course of business.

Realized gains and losses from SCE's derivative instruments are expected to be recovered from or refunded to customers through regulatory mechanisms and, therefore, SCE's fair value changes have no impact on purchased power expense or earnings. SCE does not use hedge accounting for derivative transactions due to regulatory accounting treatment.

Where SCE's derivative instruments are subject to a master netting agreement and certain criteria are met, SCE presents its derivative assets and liabilities on a net basis on its consolidated balance sheets. In addition, derivative positions are offset against margin and cash collateral deposits. The results of derivative activities are recorded as part of cash flows from operating activities on the consolidated statements of cash flows. See Note 6 for further information on derivative instruments.

Leases

A lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets for a period of time in exchange for consideration. An entity controls the use when it has a right to obtain substantially all of the benefits from the use of the asset and has the right to direct the use. SCE determines if an arrangement is a lease at contract inception. For all classes of underlying assets, except battery storage assets where each component is separately accounted for, SCE accounts for lease and non-lease components as a single lease component. Lease liabilities are recognized based on the present value of the lease payments over the lease term at the commencement date. SCE calculates and uses the rate implicit in the lease if the information is readily available or if not available, SCE uses its incremental borrowing rate in determining the present value of lease payments. Incremental borrowing rates are comprised of underlying risk-free rates and secured credit spreads relative to first mortgage bonds with like tenors of lease term durations. Lease right-of-use ("ROU") assets are based on the liability, subject to adjustments, such as lease incentives. The ROU assets also include any lease payments made at or before the commencement date. SCE excludes variable lease payments in measuring lease assets and lease liabilities. SCE's lease terms include options to extend or terminate the lease when it is reasonably certain that such options will be exercised. SCE elected to exclude from the balance sheet short-term leases of one year or less.

SCE enters into power purchase agreements that may contain leases. This occurs when a power purchase agreement designates a specific power plant, SCE obtains substantially all of the economic benefits from the use of the plant and has the right to direct the use of the plant. SCE also enters into a number of agreements to lease property and equipment

in the normal course of business, primarily related to vehicles, office space and other equipment. See Note 13 for further information on leases.

Edison International Parent and Other's leases primarily relate to Edison Energy, which are immaterial to Edison International.

Stock-Based Compensation

Stock options, performance shares, deferred stock units and restricted stock units have been granted under Edison International's long-term incentive compensation programs. For equity awards that are settled in common stock, Edison International either issues new common stock, or uses a third party to purchase shares from the market and deliver such shares for the settlement of the awards. Stock options, performance shares, deferred stock units and restricted stock units are settled in common stock. For awards that are otherwise settled entirely in common stock, Edison International substitutes cash awards to the extent necessary to satisfy applicable tax withholding obligations or government levies.

Stock-based compensation expense is recognized, net of estimated forfeitures, on a straight-line basis over the requisite service period based on estimated fair values. For equity awards paid in common stock, fair value is determined at the grant date. For equity awards that have market conditions defined in the grants, expense is recognized based on grant date fair value if the requisite service period is fulfilled. However, with respect to the portion of the performance shares payable in common stock that are subject to financial performance conditions defined in the grants, the number of performance shares expected to be earned is subject to revision and updated at each reporting period, with a related adjustment to compensation expense.

For awards granted to retirement-eligible participants, stock compensation expense is recognized on a prorated basis over the initial year. For awards granted to participants who become eligible for retirement during the requisite service period, stock compensation expense is recognized over the period between the date of grant and the date the participant first becomes eligible for retirement. Edison International and SCE estimate the number of awards that are expected to vest rather than account for forfeitures when they occur. Share-based payments may create a permanent difference between the amount of compensation expense recognized for book and tax purposes. The tax impact of this permanent difference is recognized in earnings in the period it is created. See Note 9 for further information.

Employee Stock Purchase Plan

The Edison International Employee Stock Purchase Plan ("ESPP"), effective beginning July 2021, allows eligible employees to make purchases of Edison International's common stock. The maximum aggregate numbers of shares that may be issued under the ESPP is 3,000,000 shares. Eligible employees may authorize payroll deductions of between 1% and 10% of their compensation, up to a maximum of $25,000, to purchase shares of common stock at 97% of the market price on the last day of each six months offering period. The ESPP is considered noncompensatory and stock issuances under the ESPP are recorded directly in equity.

SCE Dividends

CPUC holding company rules require that SCE's dividend policy be established by SCE's Board of Directors on the same basis as if SCE were a stand-alone utility company, and that the capital requirements of SCE, as deemed to be necessary to meet SCE's electricity service obligations, shall receive first priority from the Boards of Directors of both Edison International and SCE. In addition, the CPUC regulates SCE's capital structure which limits the dividends it may pay to its shareholders.

The common equity component of SCE's CPUC authorized capital structure is 52% on a weighted average basis over the January 1, 2023 to December 31, 2025 compliance period ("Capital Structure Compliance Period"). The CPUC authorized capital structure differs from the capital structure calculated based on GAAP due to certain exclusions

allowed by CPUC, including the impact of SCE's contributions to the Wildfire Insurance Fund under AB 1054.

In August 2023, the CPUC issued a decision on SCE's application to the CPUC for an extension of the waiver of compliance with its equity ratio requirement that allows SCE to exclude from its equity ratio calculations (i) net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events and (ii) debt issued for the purpose of paying claims, and associated expenses, related to the 2017/2018 Wildfire/Mudslide Events up to an amount equal to the net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events. Under the decision, effective as of the beginning of the new cost of capital cycle on January 1, 2023, the CPUC also authorized SCE to exclude from its equity ratio calculations debt that exceeds the net charges accrued in connection with the 2017/2018 Wildfire/Mudslide Events due to the timing difference between the wildfire claims payment and the realization of the cash tax benefits. The temporary exclusion will lapse on August 31, 2025 or when determinations regarding cost recovery for the 2017/2018 Wildfire/Mudslide Events are made, whichever comes earlier. If the CPUC has not made determinations regarding cost recovery by August 31, 2025, SCE is permitted to file another application for a waiver of compliance with its equity ratio requirement. While the exclusion is in place, SCE is required to notify the CPUC if an adverse financial event reduces SCE's spot equity ratio by more than one percent from the level most recently filed with the CPUC in the proceeding. The last spot equity ratio SCE filed with the CPUC in the proceeding did not exclude the then $1.8 billion net charge and was 45.2% as of December 31, 2018 (at the time the common equity component of SCE's CPUC authorized capital structure was required to remain at or above 48% on a weighted average basis over the applicable 37-month period). SCE's spot equity ratio on December 31, 2018 would have been 48.7% had the $1.8 billion net charge at December 31, 2018 been excluded, therefore SCE will notify the CPUC if its spot ratio drops below 47.7% in any quarter. For further information, see "Note 12. Commitments and Contingencies—Contingencies—Southern California Wildfires and Mudslides."

SCE monitors its compliance with the CPUC's equity ratio requirement based on the weighted average of the common equity component of SCE's CPUC authorized capital structure over the Capital Structure Compliance Period using its actual capital structure from the beginning of the Capital Structure Compliance Period through the reporting date together with forecasted performance and expected financing activities for the remainder of the Capital Structure Compliance Period. SCE expects to be compliant with its CPUC authorized capital structure at the end of the Capital Structure Compliance Period.

SCE's ability to declare and pay common dividends may be restricted under the terms of its outstanding series of preference stock. For further information see Note 14.

As a California corporation, SCE's ability to pay dividends is also governed by the California General Corporation Law. California law requires that for a dividend to be declared: (a) retained earnings must equal or exceed the proposed dividend, or (b) immediately after the dividend is made, the value of the corporation's assets must exceed the value of its liabilities plus amounts required to be paid, if any, in order to liquidate stock senior to the shares receiving the dividend. Additionally, a California corporation may not declare a dividend if it is, or as a result of the dividend would be, likely to be unable to meet its liabilities as they mature. Prior to declaring dividends, SCE's Board of Directors evaluates available information, including when applicable, information pertaining to the 2017/2018 Wildfire/Mudslide Events, to ensure that the California law requirements for the declarations are met. On February 22, 2024, SCE declared a dividend to Edison International of $360 million.

The timing and amount of future dividends are also dependent on a number of other factors including SCE's requirements to fund other obligations and capital expenditures, and its ability to access the capital markets and generate operating cash flows and earnings. If SCE incurs significant costs related to catastrophic wildfires and is unable to recover such costs through insurance, the Wildfire Insurance Fund (for fires after July 12, 2019), or from customers or is unable to access capital markets on reasonable terms, SCE may be limited in its ability to pay future dividends to Edison International and its preference shareholders.

Edison International Dividend

In December 2023, Edison International declared a 5.8% increase to the annual dividend rate from $2.95 per share to $3.12 per share. On February 22, 2024, Edison International declared a dividend of $0.78 per share to be paid on April 30, 2024. Edison International intends to maintain its target payout ratio of 45% – 55% of SCE's core earnings.

Earnings Per Share

Edison International computes earnings per common share ("EPS") using the two-class method, which is an earnings allocation formula that determines EPS for each class of common stock and participating security. Edison International's participating securities are stock-based compensation awards, payable in common shares, which earn dividend equivalents on an equal basis with common shares once the awards are vested. See Note 9 and Note 14 for further information.

EPS attributable to Edison International common shareholders was computed as follows:

	Years ended December 31,
(in millions, except per-share amounts)	2023		2022		2021
Basic earnings per share:
Net income attributable to common shareholders	$	1,197	$	612	$	759
Net income available to common shareholders	$	1,197	$	612	$	759
Weighted average common shares outstanding		383		381		380
Basic earnings per share	$	3.12	$	1.61	$	2.00
Diluted earnings per share:
Net income attributable to common shareholders	$	1,197	$	612	$	759
Net income available to common shareholders	$	1,197	$	612	$	759
Income impact of assumed conversions		1		1		1
Net income available to common shareholders and assumed conversions	$	1,198	$	613	$	760
Weighted average common shares outstanding		383		381		380
Incremental shares from assumed conversions		2		2		—
Adjusted weighted average shares – diluted		385		383		380
Diluted earnings per share	$	3.11	$	1.60	$	2.00

In addition to the participating securities discussed above, Edison International also may award stock options, which are payable in common shares and are included in the diluted earnings per share calculation. Stock option awards to purchase 3,771,766, 5,839,549 and 10,239,501, of common stock for the years ended December 31, 2023, 2022 and 2021, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the effect would have been antidilutive.

Income Taxes

Edison International and SCE estimate their income taxes for each jurisdiction in which they operate. This involves estimating current period tax expense along with assessing temporary differences resulting from the differing treatment of items (such as depreciation) for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in the consolidated balance sheets.

Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Interest income, interest expense, and penalties associated with income taxes are generally reflected in "Income tax expense (benefit)" on the consolidated statements of income.

Edison International's eligible subsidiaries are included in Edison International's consolidated federal income tax and combined state tax returns. Edison International has tax-allocation and payment agreements with certain of its

subsidiaries. Pursuant to an income tax-allocation agreement approved by the CPUC, SCE's tax liability is computed as if it filed its federal and state income tax returns on a separate return basis.

New Accounting Guidance

Accounting Guidance Adopted

No material accounting standards were adopted in 2023.

Accounting Guidance Not Yet Adopted

In November 2023, the FASB issued an accounting standards update to enhance the disclosures related to public entities' reportable segments. The new guidance requires an entity with only one reportable segment to include all the required segment disclosures. The guidance will be effective for annual disclosures for the year ended December 31, 2024 and subsequent interim periods with early adoption permitted. The guidance is applied retrospectively to all periods presented in the financial statements. Edison International and SCE have one reportable segment and are currently evaluating the impact of any increased segment disclosures.

In December 2023, the FASB issued an accounting standards update requiring public entities to provide more disclosures primarily related to the income tax rate reconciliation and income taxes paid. The guidance also eliminates certain existing disclosure requirements related to uncertain tax positions and unrecognized deferred tax liabilities. The guidance is effective January 1, 2025 with early adoption permitted. The guidance is applied prospectively. Edison International and SCE are currently evaluating the impact of the new guidance.