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Summary of Significant Accounting Policies | 12 Months Ended
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Dec. 31, 2017
Accounting Policies [Abstract] |
Summary of Significant Accounting Policies | Summary of Significant Accounting Policies 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 subsidiaries, including Edison Energy, LLC ("Edison Energy") and SoCore Energy LLC ("SoCore Energy"), engaged in pursuing competitive business opportunities across energy services, managed portfolio solutions, and distributed solar solutions for commercial and industrial customers. Such 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. 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 10 for composition of regulatory assets and liabilities. 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 Cash equivalents includes 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) | 2017 |  | 2016 |  | 2017 |  | 2016
Money market funds | $ | 1,024 |  |  | $ | 41 |  |  | $ | 483 |  |  | $ | 18 |
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) | 2017 |  | 2016 |  | 2017 |  | 2016
Book balances reclassified to accounts payable | $ | 64 |  |  | $ | 138 |  |  | $ | 63 |  |  | $ | 136 |
Restricted Cash Edison International's restricted cash at December 31, 2017 and 2016 were $41 million and $18 million, respectively. Restricted cash primarily relates to funds held by SoCore Energy and its consolidated affiliates pursuant to project financing or purchase agreements; most of which are expected to lapse by the end of 2018. 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 SCE's inventory is primarily composed of materials, supplies and spare parts, and generally stated at average cost. Emission Allowances 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 had GHG allowances of $127 million and $113 million at December 31, 2017 and 2016, respectively. GHG emission obligations were $129 million and $95 million at December 31, 2017 and 2016, respectively, and are classified as "Other current liabilities" on the consolidated balance sheets. 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) 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 55 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. Depreciation expense was $1.61 billion, $1.52 billion and $1.42 billion for 2017, 2016 and 2015, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 3.8%, 3.8% and 3.9% for 2017, 2016 and 2015, 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 $87 million, $74 million and $87 million in 2017, 2016 and 2015, respectively, and is reflected in "Interest and other income." AFUDC debt was $28 million, $23 million and $31 million in 2017, 2016 and 2015, 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 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. Goodwill Edison International assesses goodwill through annual goodwill impairment tests, at the reporting unit level as of October 1st of each year. Edison International will update these tests 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. During 2017, Edison International completed a strategic review of Edison Energy Group's competitive businesses. Edison International has concluded that it will evaluate strategic options, including potential sale opportunities, for SoCore Energy. In connection with the strategic review of the Edison Energy Group's competitive businesses, Edison International evaluated the recoverability of goodwill and recorded an impairment of SoCore Energy's goodwill totaling $16.5 million ($10 million after-tax) in the second quarter of 2017. The fair value of the Edison Energy and SoCore Energy reporting units exceeded their carrying values at the date of the impairment analysis. As of December 31, 2017 and 2016, goodwill is comprised of $78 million at each year end at the Edison Energy reporting unit and $5 million and $22 million, respectively, at the SoCore Energy reporting unit. 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 Notes 9 and 10. SCE has not recorded an asset retirement obligation 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, including San Onofre Nuclear Generating Station ("San Onofre") and Palo Verde:
| December 31,
(in millions) | 2017 |  | 2016
Beginning balance | $ | 2,586 |  |  | $ | 2,762 |
Accretion 1 | 166 |  |  | 157 |
Revisions | 376 |  |  | (165 | )
Liabilities settled | (236 | ) |  | (168 | )
Ending balance | $ | 2,892 |  |  | $ | 2,586 |
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 recorded liability to decommission SCE's nuclear power facilities (included in the table above) is $2.6 billion as of December 31, 2017. In 2016, SCE updated the recorded liability for Palo Verde and San Onofre Unit 1 based on the 2013 decommissioning study performed for Palo Verde and the 2014 study for San Onofre Unit 1. In 2017, SCE further revised the recorded liability for Palo Verde and San Onofre Units 2 and 3 based on updated cost estimates, including changes related to onboarding the general contractor. The final site specific study for San Onofre Units 2 and 3 is expected to be filed in March 2018 as part of the 2018 NDCTP which may result in additional changes to the ARO estimate. 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 increases 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 1.6% 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. See Note 9 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 and equity investments that are classified as available-for-sale. Due to regulatory mechanisms, earnings and realized gains and losses (including other-than-temporary impairments) have no impact on earnings. Unrealized gains and losses on decommissioning trust funds 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 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 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. SCE had unamortized losses on reacquired debt of $168 million and $184 million at December 31, 2017 and 2016, respectively, reflected as long-term "Regulatory assets" in the consolidated balance sheets. Edison International and SCE had unamortized debt issuance costs related to issuances under the credit facilities of $15 million and $7 million at December 31, 2017, respectively, and $10 million and $7 million at December 31, 2016, respectively, reflected in "Other long-term assets" on the consolidated balance sheets. In addition, Edison International and SCE had debt issuance costs related to issuances of long-term debt of $88 million and $77 million at December 31, 2017, respectively, and $81 million and $71 million at December 31, 2016, respectively, reflected as a reduction of "Long-term debt" on the consolidated balance sheets. Amortization of deferred financing costs charged to interest expense is as follows:
| Edison International |  | SCE
| Years ended December 31,
(in millions) | 2017 |  | 2016 |  | 2015 |  | 2017 |  | 2016 |  | 2015
Amortization of deferred financing costs charged to interest expense | $ | 30 |  |  | $ | 31 |  |  | $ | 33 |  |  | $ | 27 |  |  | $ | 27 |  |  | $ | 28 |
Revenue Recognition Revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the end of each reporting period as reflected in "Operating revenue" on the consolidated statements of income. Rates charged to customers are based on CPUC- and FERC-authorized revenue requirements. CPUC rates are implemented subsequent to final approval. CPUC rates decouple authorized revenue from the volume of electricity sales. Differences between amounts collected and authorized levels are either collected from or refunded to customers, and therefore, SCE earns revenue equal to amounts authorized. FERC rates also decouple revenue from volume of electricity sales. In November 2013, the FERC approved a formula rate effective January 1, 2012 to determine SCE's FERC transmission revenue requirement, including its construction work in progress ("CWIP") revenue requirement. Under operation of the formula rate, transmission revenue will be updated to actual cost of service annually. Differences between amounts collected and determined under the formula rate are either collected from or refunded to customers, and therefore, SCE earns revenue based on estimates of recorded rate base costs under the FERC formula rate. 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 and reflected in electric utility revenue and other operation and maintenance expense. SCE's franchise fees billed to customers and recorded as revenue were $133 million, $111 million and $138 million in 2017, 2016 and 2015, respectively. When SCE acts as an agent, 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. Power Purchase Agreements SCE enters into power purchase agreements 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 power purchase agreements resulted in consolidation of a VIE at December 31, 2017 and 2016. See Note 3 for further discussion of power purchase agreements that are considered variable interests. A power purchase agreement may also contain a lease for accounting purposes. This generally occurs when a power purchase agreement designates a specific power plant in which the buyer purchases substantially all of the output and does not otherwise meet a fixed price per unit of output exception. SCE has a number of power purchase agreements that contain leases. SCE's recognition of lease expense conforms to the ratemaking treatment for SCE's recovery of the cost of electricity and is recorded in "Purchased power and fuel" on the consolidated statements of income. See Note 11 for further discussion of SCE's power purchase agreements, including agreements that are classified as operating and capital leases for accounting purposes. A power purchase agreement that does not contain a lease may be classified as a derivative which is recorded at fair value on the consolidated balance sheets. These power purchase agreements 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. Power purchase agreements 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. 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 SCE enters into power purchase agreements that may contain leases, as discussed under "Power Purchase Agreements" above. SCE also enters into a number of agreements to lease property and equipment in the normal course of business. 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 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. Effective January 1, 2016, the excess tax benefits are classified as an operating activity along with other income tax cash flows on the statement of cash flows. SCE Dividend Restrictions The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. Under CPUC regulations, SCE may make distributions to Edison International as long as the common equity component of SCE's capital structure remains at or above 48% on a 13-month average basis, or otherwise satisfies the CPUC requirements. If the Revised San Onofre Settlement Agreement is approved by the CPUC, SCE may exclude the $448 million after-tax charge resulting from the implementation of the Revised San Onofre Settlement Agreement from its ratemaking capital structure. See Note 11 for discussion of the Revised San Onofre Settlement Agreement. At December 31, 2017, without excluding the $448 million after-tax charge, SCE's 13-month average common equity component of total capitalization was 50.0% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $511 million, resulting in a restriction on net assets of approximately $14.2 billion. If the Revised San Onofre Settlement Agreement had been approved by the CPUC at December 31, 2017, the common equity component of SCE's capital structure would have been 50.1% on a 13-month average basis. 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, including performance shares and restricted stock units, which earn dividend equivalents on an equal basis with common shares once the awards are vested. Performance shares awarded prior to 2015 that are earned are settled half in common shares and half in cash, while the performance shares awarded on or after 2015 that are earned are settled solely in cash. For further information, see Note 8. EPS attributable to Edison International common shareholders was computed as follows:
| Years ended December 31,
(in millions, except per-share amounts) | 2017 |  | 2016 |  | 2015
Basic earnings per share – continuing operations: |  |  |  |  |
Income from continuing operations attributable to common shareholders | $ | 565 |  |  | $ | 1,299 |  |  | $ | 985 |
Participating securities dividends | — |  |  | — |  |  | (1 | )
Income from continuing operations available to common shareholders | $ | 565 |  |  | $ | 1,299 |  |  | $ | 984 |
Weighted average common shares outstanding | 326 |  |  | 326 |  |  | 326 |
Basic earnings per share – continuing operations | $ | 1.73 |  |  | $ | 3.99 |  |  | $ | 3.02 |
Diluted earnings per share – continuing operations: |  |  |  |  |
Income from continuing operations attributable to common shareholders | $ | 565 |  |  | $ | 1,299 |  |  | $ | 985 |
Participating securities dividends | — |  |  | — |  |  | (1 | )
Income from continuing operations available to common shareholders | $ | 565 |  |  | $ | 1,299 |  |  | $ | 984 |
Income impact of assumed conversions | — |  |  | 1 |  |  | 1 |
Income from continuing operations available to common shareholders and assumed conversions | $ | 565 |  |  | $ | 1,300 |  |  | $ | 985 |
Weighted average common shares outstanding | 326 |  |  | 326 |  |  | 326 |
Incremental shares from assumed conversions | 2 |  |  | 4 |  |  | 3 |
Adjusted weighted average shares – diluted | 328 |  |  | 330 |  |  | 329 |
Diluted earnings per share – continuing operations | $ | 1.72 |  |  | $ | 3.94 |  |  | $ | 2.99 |
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 1,334,451, 167,795 and 2,046,045 shares of common stock for the years ended December 31, 2017, 2016 and 2015, 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 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 7 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 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. Certain solar projects for commercial customers are organized as limited liability companies and have noncontrolling equity investors (referred to as tax equity investors) which are entitled to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary over time. These entities are consolidated for financial reporting purposes but are not subject to income taxes as the taxable income (loss) and investment tax credits are allocated to the respective owners. The total consolidated assets and liabilities of these entities were $299 million and $41 million, respectively, at December 31, 2017 and $74 million and $23 million, respectively, at December 31, 2016. Income (loss) of these entities is allocated to the noncontrolling interest based on the hypothetical liquidation at book value ("HLBV") accounting method. The HLBV accounting method is an approach that calculates the change in the claims of each member on the net assets of the investment at the beginning and end of each period. Each member's claim is equal to the amount each party would receive or pay if the net assets of the investment were to liquidate at book value. Under the contract provisions, the tax equity investors' claim on net assets decreases rapidly in early years due to allocation of tax benefits resulting in additional non-operating income allocated to Edison International ($21 million, $9 million and $16 million in 2017, 2016 and 2015, respectively). New Accounting Guidance Accounting Guidance Not Yet Adopted In May 2014, the FASB issued an accounting standards update on revenue recognition and further amended the standard in 2016 and 2017. Under the new standard, revenue from contracts with customers is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. For the year ended December 31, 2017, approximately 95% of total operating revenue arises from SCE's tariff offerings that provide electricity to customers. For such arrangements, revenue from contracts with customers will be equivalent to the electricity supplied and billed in that period (including estimated billings). As such, there will not be a change in the timing or pattern of revenue recognition for such sales. Edison International and SCE have implemented process changes necessary to comply with this standard's enhanced disclosure requirements. SCE will disaggregate customer contract revenue between revenue from earnings activities and revenue from cost-recovery activities. 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 will adopt the standard by using the modified retrospective method. Edison International will recognize an immaterial cumulative effect adjustment to the opening balance of retained earnings on January 1, 2018. In January 2016, the FASB issued an accounting standards update that amends the guidance on the classification and measurement of financial instruments. The amendments require equity investments (excluding those accounted for under the equity method or those that result in consolidation) to be measured at fair value, with changes in fair value through net income. It also amends certain disclosure requirements associated with the fair value of financial instruments. In addition, the new guidance 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 will adopt this guidance effective January 1, 2018. SCE's nuclear decommissioning trust investments contain equity investments that are classified as available-for-sale. Due to regulatory mechanisms, the change in fair value of these investments has no impact on net income and, therefore, the adoption of this standard will not have a material impact on Edison International's and SCE's consolidated financial statements. In February 2016, the FASB issued an accounting standards update related to lease accounting, 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 for a period of time in exchange for consideration. Lessees will need 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 lease payments. The asset will be based on the liability, subject to adjustments, such as initial direct costs. Edison International operating leases will result in straight-line expense while finance leases will result in a higher initial expense pattern due to the interest component. SCE, as a regulated entity, is permitted to continue to recognize expense using the timing that conforms to the regulatory rate treatment. Lessees can elect to exclude from the balance sheet short-term contracts of one year or less. The standard requires retrospective application to previously issued financial statements for 2018 and 2017. Although permitted, Edison and SCE will not elect to adopt this standard prior to January 1, 2019. The standard will provide entities with an optional transition method to apply the new requirements in the period of adoption without retrospective application to previous periods. Edison International and SCE are evaluating whether to elect this optional transition method. The adoption of this standard will increase right-of-use assets and lease liabilities in Edison International's and SCE's consolidated balance sheets. Edison International and SCE are currently implementing a new lease accounting system and are evaluating the impact this standard will have on the consolidated balance sheets and lease disclosures. The FASB issued an accounting standards update 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. The FASB issued two accounting standards updates related to the statement of cash flows. One standards update clarifies the presentation and classification of certain cash receipts and payments in the statement of cash flows and the other requires restricted cash to be presented with cash and cash equivalents in the statement of cash flows. These standards are effective January 1, 2018 and require retrospective application. Restricted cash as of December 31, 2017 was $41 million at Edison International and was less than $1 million at SCE. Currently, the changes in restricted cash balances are reflected as operating or investing activities dependent on the nature of the activities. In January 2017, the FASB issued an accounting standards update to simplify the accounting for goodwill impairment. This accounting standards update changes the procedural steps in applying the goodwill impairment test. A goodwill impairment will now be 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 the goodwill impairment test beginning in 2020. In March 2017, the FASB issued an accounting standards update which amends the current requirements related to the presentation of the components of net periodic benefit cost for an entity's defined benefit pension and other postretirement plans. The adoption of this standard is not expected to have a material impact on Edison International's and SCE's financial position or results of operations, but will result in the separate presentation of service costs as an operating expense and non-service costs within other income and expense and limit the capitalization of benefit costs to the service cost component. For the year ended December 31, 2017, service costs totaled $169 million for Edison International and $164 million for SCE and the non-service component of net periodic benefit cost was income of $72 million for Edison International and $84 million for SCE. The new standards update is effective on January 1, 2018 and is required to be adopted retrospectively with respect to the income statement presentation requirement and prospectively for the capitalization requirement.

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