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Summary of Significant Accounting Policies (Policies) | 12 Months Ended
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Dec. 31, 2018
Accounting Policies [Abstract] |
Organization and Basis of Presentation | Organization and Basis of Presentation Edison International is the parent holding company of Southern California Edison Company ("SCE") and Edison Energy Group, Inc. ("Edison Energy Group"). 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 Group is a holding company for Edison Energy, LLC ("Edison Energy") which is engaged in the competitive business of providing energy services to commercial and industrial customer. 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 wholly owned and 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 and its wholly owned and controlled subsidiaries. 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, 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 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 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, even for programs that do not qualify for recognition of "traditional" regulatory assets and liabilities. 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.
Use of Estimates | The preparation of financial statements in conformity with United States generally accepted accounting principles ("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.
Cash Equivalents and Restricted Cash | Cash Equivalents and Restricted Cash Cash equivalents include 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) | 2018 |  | 2017 |  | 2018 |  | 2017
Money market funds | $ | 116 |  |  | $ | 1,024 |  |  | $ | 1 |  |  | $ | 483 |
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 as follows:
| Edison International |  | SCE
| December 31,
(in millions) | 2018 |  | 2017 |  | 2018 |  | 2017
Book balances reclassified to accounts payable | $ | 65 |  |  | $ | 64 |  |  | $ | 65 |  |  | $ | 63 |
Edison International's restricted cash at December 31, 2018 and 2017 were $8 million and $41 million, respectively. Restricted cash at December 31, 2017 primarily relates to funds held by SoCore Energy and its consolidated affiliates pursuant to project financing or purchase agreements, most of which lapsed before June 30, 2018.
Allowance for Uncollectible Accounts | Allowance for Uncollectible Accounts Allowances for uncollectible accounts are provided based upon a variety of factors, including historical amounts written-off, current economic conditions and assessment of customer collectability.
Inventory | Inventory SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at average cost.
Emission Allowances and Energy Credits | 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.
Property, Plant and Equipment | 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, pension and 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 2015 GRC) and weighted-average useful lives of SCE's property, plant and equipment, are as follows:
| Estimated Useful Lives | Weighted-Average Useful Lives
Generation plant | 10 years to 54 years | 37 years
Distribution plant | 20 years to 60 years | 43 years
Transmission plant | 40 years to 65 years | 52 years
General plant and other | 5 years to 60 years | 22 years
Depreciation of utility property, plant and equipment is computed on a straight-line, remaining-life basis. SCE's depreciation expense was $1.65 billion, $1.61 billion and $1.52 billion for 2018, 2017 and 2016, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.7%, 3.8% and 3.8% for 2018, 2017 and 2016, respectively. The original costs of retired property is charged to accumulated depreciation. 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 $104 million, $87 million and $74 million in 2018, 2017 and 2016, respectively, and is reflected in "Other income and expenses." AFUDC debt was $44 million, $28 million and $23 million in 2018, 2017 and 2016, respectively and is reflected as a reduction of "Interest expense." Major Maintenance Major maintenance costs for SCE's power plant facilities and equipment are expensed as incurred.
Impairment of Long-Lived Assets | 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 amount of the disallowance can be made.
Goodwill | Goodwill Edison International assesses goodwill through an annual goodwill impairment test, at the reporting unit level as of October 1st of each year. Edison International updates its goodwill impairment test between annual tests if events occur or circumstances change such that it is more likely than not that the fair value of a reporting unit is below its carrying value. In assessing goodwill for impairment, Edison International may perform a qualitative assessment to determine whether a quantitative assessment is necessary. In performing a qualitative assessment, Edison International assesses, among other things, macroeconomic conditions, industry and market considerations, overall financial performance, cost factors and entity-specific events. If, after assessing these qualitative factors, Edison International determines that it is more likely than not that the fair value of a reporting unit is less than its carrying amount, then Edison International performs the two-step goodwill impairment test ("quantitative assessment").
Nuclear Decommissioning and Asset Retirement Obligations | 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. 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. SCE adjusts its nuclear decommissioning obligation into a nuclear-related ARO regulatory asset and also 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. 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) | 2018 |  | 2017
Beginning balance | $ | 2,892 |  |  | $ | 2,586 |
Accretion 1 | 169 |  |  | 166 |
Revisions | 110 |  |  | 376 |
Liabilities settled | (140 | ) |  | (236 | )
Ending balance | $ | 3,031 |  |  | $ | 2,892 |
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.
The ARO for decommissioning SCE's San Onofre Nuclear Generating Station ("San Onofre") and Palo Verde nuclear power facilities is $2.8 billion as of December 31, 2018. The liability to decommission SCE's nuclear power facilities is based on a 2017 decommissioning study that was filed as part of the 2018 NDTCP for San Onofre Units 1, 2, and 3, with revisions to the cost estimate in 2018 for San Onofre Units 2 and 3 and a 2016 decommissioning study for Palo Verde, with revisions to the cost estimate in 2017. SCE revised the ARO for San Onofre Units 2 and 3 due to increases in decommissioning cost estimates in 2018, related to the impact of operational uncertainties, and in 2017, related to changes to onboarding the general contractor at San Onofre. The initial activity phase of radiological decommissioning of San Onofre Units 2 and 3 began in June 2013 with SCE filing a certification of permanent cessation of power operations at San Onofre with the Nuclear Regulatory Commission and some spent nuclear fuel was transferred to dry cask storage in the Independent Spent Fuel Storage Installation ("ISFSI") between 2007 and 2012. The transfer of the remaining spent nuclear fuel from Units 2 and 3 to the ISFSI began in 2018. However, the spent fuel transfer operations were suspended on August 3, 2018 due to an incident that occurred when an SCE contractor was loading a spent fuel canister into the ISFSI. The incident did not result in any harm to the public or workers and the canister was subsequently safely loaded into the ISFSI. SCE cannot predict when fuel transfer operations at San Onofre will recommence. 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. 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 $7.2 billion through 2079 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 2.4% to 3.8%. Future decommissioning costs related to SCE's nuclear assets are expected to be funded from independent decommissioning trusts. 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 proceeding. 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 other-than-temporary 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 other-than-temporary impairment on the last day of each month. If the fair value on the last day of two consecutive months is less than the cost for that security, SCE recognizes a loss for the other-than-temporary impairment. 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 | Deferred Financing Costs Debt premium, discount and issuance expenses incurred in connection with obtaining financing are deferred and amortized on a straight-line basis. 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.
Revenue Recognition | 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 GRC proceeding, for the three-year period 2018 – 2020, is pending. SCE has requested a revenue requirement of $5.534 billion for its test year of 2018, a $106 million decrease from the 2017 GRC authorized revenue requirement, and revenue requirements for the post-test years of 2019 and 2020 of $5.965 billion and $6.468 billion, respectively. In the absence of a 2018 GRC decision, SCE recognized revenue in 2018 and is recognizing revenue in 2019 based on the 2017 authorized revenue requirement, adjusted for the July 2017 cost of capital decision and Tax Reform. The CPUC has approved the establishment of a GRC memorandum account and the 2018 and 2019 revenue requirements adopted by the CPUC will be effective as of January 1, 2018 and January 1, 2019, respectively. The amounts billed to customers for the year ended December 31, 2018 were based on the 2017 authorized revenue requirement and a regulatory liability has been established to record the associated adjustments. See Note 11 for further details. SCE accounts for regulatory decisions in the discrete period in which they are received and, accordingly, will record the impact of the 2018 GRC decision when a decision is received. In October 2017, SCE filed its new formula rate with the FERC. In December 2017, the FERC issued an order setting the effective date of SCE's new FERC formula rate as of January 1, 2018, subject to settlement procedures and refund. Pending resolution of the FERC formula rate proceeding, SCE is recognizing revenue based on the FERC formula rate adjusted for the impact of Tax Reform and other adjustments. 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.
Power Purchase Agreements | 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 should consolidate the VIE. None of SCE's PPAs resulted in consolidation of a VIE at December 31, 2018 and 2017. 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 for further discussion of SCE's PPAs, including agreements that are classified as operating and capital leases for accounting purposes. 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. These PPAs may be eligible for an election to designate as a normal purchase and sale, which is accounted for on an accrual basis as an executory contract. See Note 6 for further information on derivative instruments. PPAs that do not meet the above classifications are accounted for on an accrual basis.
Derivatives Instruments | 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. During the third quarter of 2017, SCE designated certain derivative contracts as normal purchase and normal sale contracts, which resulted in a reclassification of $914 million from derivative liabilities to other liabilities. These liabilities will be amortized over the remaining contract terms. 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 | Leases SCE enters into PPAs that may contain leases, as discussed under "Power Purchase Agreements" above. A PPA contains a lease when SCE purchases substantially all of the output from a specific plant and does not otherwise meet a fixed price per unit of output exception. 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. Minimum lease payments under SCE's operating leases for property and equipment are reflected in "Operation and maintenance" on the consolidated statements of income.
Stock-Based Compensation | 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. Generally, Edison International does not issue new common stock for settlement of equity awards, which are recorded as part of retained earnings. Rather, a third party is used to purchase shares from the market and deliver such shares for the settlement of option exercises, performance shares, deferred stock units and restricted stock units. The performance shares awarded that are earned are settled solely in cash. Deferred stock units and restricted stock units are settled in common stock; however, Edison International will substitute cash awards to the extent necessary to pay tax withholding or any government levies. Stock-based compensation expense is recognized on a straight-line basis over the requisite service period and is based on the number of awards that are expected to vest. Edison International and SCE estimate the number of awards that are expected to vest rather than account for forfeitures when they occur. For awards granted to retirement-eligible participants, stock compensation expenses are 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 expenses are recognized over the period between the date of grant and the date the participant first becomes eligible for retirement. Under new accounting guidance adopted in 2016, 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.
SCE Dividend Restrictions | 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. Under SCE's interpretation of CPUC regulations, the common equity component of SCE's capital structure must remain at or above 48% on a weighted average basis over the 37-month period that SCE's capital structure is in effect for ratemaking purposes.
Earnings Per Share | 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.
Income Taxes | 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 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. In December 2017, the Tax Cuts and Jobs Act ("Tax Reform") was signed into law. This comprehensive reform of tax law reduces the federal corporate income tax rate from 35% to 21% which resulted in the re-measurement of deferred taxes using the new tax rate. See Note 8 for further information. Income tax expense includes the current tax liability from operations and the change in deferred income taxes during the year. Investment tax credits are deferred and amortized to income tax expense over the lives of the properties or the term of the power purchase agreement of the respective project. Interest income, interest expense and penalties associated with income taxes are reflected in "Income tax expense" 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.
Noncontrolling Interest | Noncontrolling Interest Noncontrolling interest represents the portion of equity ownership in an entity that is not attributable to the equity holders of Edison International. Noncontrolling interests held by third parties that have rights to put their ownership back to a subsidiary of Edison International are classified outside shareholders' equity as redeemable noncontrolling interest. Noncontrolling interest is initially recorded at fair value and is subsequently adjusted for income allocated to the noncontrolling interest and any distributions paid to the noncontrolling interest.
New Accounting Guidance | New Accounting Guidance Accounting Guidance Adopted In May 2014, the Financial Accounting Standards Board ("FASB") issued an accounting standards update on revenue recognition and further amended the standard in 2016 and 2017. Under the new standard, revenue is recognized when a good or service is transferred to the customer and the customer obtains control of the good or service. Some revenue arrangements, such as alternative revenue programs which include balancing account overcollections and undercollections, are excluded from the scope of the new standard and, therefore, will be accounted for and presented separately from revenue recognized from contracts with customers in the disclosures. Edison International and SCE adopted this standard effective January 1, 2018, using the modified retrospective method for contracts that were not completed as of the adoption date. Edison International recognized a cumulative effect adjustment to increase the opening balance of retained earnings by approximately $5 million ($7 million pre-tax) on January 1, 2018. This adjustment is related to variable consideration recognized at Edison Energy which is not subject to potential significant reversal and has no further performance obligations. See Note 7 for further details. In January 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments, and further amended the guidance in 2018. Under the new guidance, equity investments (excluding those accounted for under the equity method or those that result in consolidation) are required to be measured at fair value, with changes in fair value recognized in net income. The new guidance also amends certain disclosure requirements associated with the fair value of financial instruments and requires financial assets and financial liabilities to be presented separately in the notes to the financial statements, grouped by measurement category and form of financial assets. Edison International and SCE adopted this guidance effective January 1, 2018. Edison International and SCE recognized a cumulative effect adjustment to increase the opening balance of retained earnings and accumulated other comprehensive loss by $5 million ($8 million pre-tax) on January 1, 2018. See Edison International's and SCE's consolidated statements of changes in equity for further details. In August and November 2016, the FASB issued two accounting standards updates to clarify the presentation and classification of certain cash receipts and payments in the statement of cash flows and to require restricted cash to be presented with cash and cash equivalents in the statement of cash flows. Edison International and SCE adopted these standards effective January 1, 2018, using the retrospective approach. The adoption of these standards did not have a material impact on Edison International's and SCE's consolidated statement of cash flows. In March 2017, the FASB issued an accounting standards update on the presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. Edison International and SCE adopted this guidance retrospectively with respect to the income statement presentation requirement and prospectively for the capitalization requirement, effective January 1, 2018. The adoption of this standard did not have a material impact on Edison International's and SCE's consolidated financial statements, but did result in the separate presentation of service costs as an operating expense and non-service costs within other income and expenses and the limitation of the capitalization of benefit costs to the service cost component. During the year ended December 31, 2017 and 2016, non-service benefits totaled $37 million and $30 million for Edison International, respectively, and $51 million and $35 million for SCE, respectively, which were reclassified from "Operation and maintenance" to "Other income and expenses." See Notes 9 and 15 for further details. Accounting Guidance Not Yet Adopted In February 2016, the FASB issued an accounting standards update related to lease accounting and further amended the standard in 2018. The new guidance is effective January 1, 2019. Under the new standard, a lease is defined as a contract, or part of a contract, that conveys the right to control the use of identified assets and obtain all the economic benefits for a period of time in exchange for consideration. Lessees are required to recognize leases on the balance sheet as a right-of-use asset and a related lease liability, and classify the leases as either operating or finance. The liability will be equal to the present value of the lease payments. The asset will be based on the liability, subject to adjustments, such as lease incentives. SCE, as a regulated entity, is permitted to continue to recognize expense using the timing that conforms to the regulatory rate treatment. In accordance with the new guidance, Edison International and SCE will elect the package of practical expedients not to reassess prior conclusions related to contracts containing leases, lease classification, and initial direct costs and the practical expedient not to assess whether existing land easements are or contain a lease. Edison International and SCE will adopt this guidance effective January 1, 2019, using the modified retrospective approach, for leases that existed as of the adoption date and will elect the optional transition method not to restate periods prior to the adoption date. The adoption of this standard is expected to increase right-of-use assets and lease liabilities in the consolidated balance sheets by approximately $1 billion as of January 1, 2019 for both Edison International and SCE. Edison International and SCE have implemented a new lease accounting system and are in the process of finalizing the impact this standard will have on the lease disclosures. The FASB issued an accounting standards update in June 2016, and further amended the guidance in November 2018, related to the impairment of financial instruments, effective January 1, 2020. The new guidance provides an impairment model, known as the current expected credit loss model, which is based on expected credit losses rather than incurred losses. Edison International and SCE are currently evaluating the impact of this new guidance. In January 2017, the FASB issued an accounting standards update to simplify the accounting for goodwill impairment by changing the procedural steps to apply the goodwill impairment test. After the adoption of this accounting standards update, goodwill impairment will be measured as the amount by which a reporting unit's carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. Edison International will apply this guidance to goodwill impairment tests beginning in 2020. In February 2018, the FASB issued an accounting standards update to provide entities an election to reclassify stranded tax effects resulting from Tax Reform from accumulated other comprehensive income to retained earnings. Stranded tax effects originated in December 2017 when deferred taxes were re-measured at the lower federal corporate tax rate with the impact included in operating income but the tax effects of items within accumulated other comprehensive income were not similarly adjusted. Edison International and SCE will adopt this guidance on January 1, 2019 and reclassify stranded tax effects of $10 million and $5 million, respectively, from accumulated other comprehensive income to retained earnings in the period of adoption. In August 2018, the FASB issued an accounting standards update which aligns the requirement for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing costs incurred to develop or obtain internal-use software. The guidance also clarified presentation requirements for reporting implementation costs in the financial statements. The guidance is effective January 1, 2020 with early adoption permitted. Edison International and SCE are currently evaluating the impact of the guidance. In August 2018, the FASB issued two accounting standards updates to remove, modify, and add certain disclosure requirements related to fair value measurement and employer-sponsored defined benefit pension or other postretirement plans. The guidance is effective January 1, 2020 and 2021, respectively, with early adoption permitted. Edison International and SCE are currently evaluating the impact of the guidance.

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