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Summary of Significant Accounting Policies | 12 Months Ended
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Dec. 31, 2014
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"). 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 International is also the parent company of subsidiaries that are engaged in competitive businesses related to the delivery or use of electricity (the "Competitive Businesses"). Such competitive 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 nonutility 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 nonregulated 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. 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. Revision in Consolidated Statements of Cash Flows The consolidated statements of cash flows of Edison International and SCE were revised to correct an error in the amount of purchases of nuclear decommissioning trust investments in the investing activities section of the consolidated statements of cash flows and in the amount attributable to the nuclear decommissioning trust in the operating activities section of the consolidated statements of cash flows. The revisions had no impact on the consolidated balance sheet, statements of income, comprehensive income, changes in equity or on the net change in cash and cash equivalents. Management believes the revisions do not have a material impact on the prior period financial statements. The following table presents the changes to the line items of the consolidated cash flow statements for the revision for the year ended December 31, 2013:
| Edison International |  | SCE
(in millions) | As Reported |  | Adjustment |  | As Revised |  | As Reported |  | Adjustment |  | As Revised
Nuclear decommissioning trusts | $ | 312 |  |  | $ | (236 | ) |  | $ | 76 |  |  | $ | 312 |  |  | $ | (236 | ) |  | $ | 76 |
Total cash provided by operating activities | 3,203 |  |  | (236 | ) |  | 2,967 |  |  | 3,284 |  |  | (236 | ) |  | 3,048 |
Purchases of nuclear decommissioning trust investments | (5,951 | ) |  | 236 |  |  | (5,715 | ) |  | (5,951 | ) |  | 236 |  |  | (5,715 | )
Total cash used by investing activities | (3,808 | ) |  | 236 |  |  | (3,572 | ) |  | (3,783 | ) |  | 236 |  |  | (3,547 | )
There were also errors identified which had an inconsequential impact on the year ended December 31, 2012, and accordingly, revision of this year was not necessary. Cash Equivalents Cash equivalents included investments in money market funds. Generally, the carrying value of cash equivalents equals the fair value, as these investments have original maturities of 3 months or less. The cash equivalents were as follows:
| Edison International |  | SCE
| December 31,
(in millions) | 2014 |  | 2013 |  | 2014 |  | 2013
Money market funds | $ | 35 |  |  | $ | 68 |  |  | $ | 5 |  |  | $ | 8 |
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) | 2014 |  | 2013 |  | 2014 |  | 2013
Book balances reclassified to accounts payable | $ | 180 |  |  | $ | 168 |  |  | $ | 177 |  |  | $ | 163 |
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 is primarily composed of materials, supplies and spare parts, and stated at the lower of cost or market, cost being determined by the average cost method. Energy Credits and Allowances Renewable energy certificates or credits ("RECs") represent rights established by governmental agencies for the environmental, social, and other nonpower qualities of renewable electricity generation. A REC, and its associated attributes and benefits, can be sold separately from the underlying physical electricity associated with a renewable-based generation source in certain markets, including California. Retail sellers of electricity obtain RECs through renewable power purchase agreements, internal generation or separate purchases in the market to comply with renewables portfolio standards established by certain such governmental agencies. RECs are the mechanism used to verify renewables portfolio standard compliance and are recognized at the lower of weighted-average cost or market when amounts purchased are in excess of the amounts needed to comply with RPS requirements. The cost of purchased RECs is recoverable as part of the cost of purchased power. 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 bilateral parties 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 $204 million and $135 million at December 31, 2014 and 2013, respectively. GHG emission obligations were $211 million and $128 million at December 31, 2014 and 2013, respectively and are classified as "Other current liabilities" on the consolidated balance sheets. Property, Plant and Equipment Plant additions, including replacements and betterments, are capitalized. SCE capitalizes as part of plant additions direct material and labor and indirect costs such as construction overhead, administrative and general costs, pension and benefits, and property taxes. The CPUC authorizes a 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 60 years | 38 years
Distribution plant | 20 years to 60 years | 40 years
Transmission plant | 40 years to 65 years | 48 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 $1.33 billion, $1.31 billion and $1.26 billion for 2014, 2013 and 2012, respectively. Depreciation expense stated as a percent of average original cost of depreciable utility plant was, on a composite basis, 4.0%, 4.2% and 4.3% for 2014, 2013 and 2012, respectively. Replaced or retired property costs are charged to the accumulated depreciation. Nuclear fuel for the Palo Verde Nuclear Power Plant 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. Nuclear fuel is amortized using the units of production method. 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 $65 million, $72 million and $96 million in 2014, 2013 and 2012, respectively. AFUDC debt was $25 million, $33 million and $40 million in 2014, 2013 and 2012, respectively. 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. SCE's impaired assets are recorded as a regulatory asset if it is deemed probable that such amounts will be recovered from customers. Due to the decision to early retire San Onofre Units 2 and 3, GAAP required reclassification of the amounts recorded in property, plant and equipment and related tangible operating assets to a regulatory asset to the extent that management concluded it was probable of recovery through future rates. Regulatory assets may also be recorded to the extent management concludes it is probable that direct and indirect costs incurred to retire Units 2 and 3 as of each reporting date are recoverable through future rates. In accordance with these requirements and as a result of its decision to retire San Onofre Units 2 and 3, SCE reclassified $1,521 million of its total investment in San Onofre at May 31, 2013 to a regulatory asset ("San Onofre Regulatory Asset") and recorded an impairment charge of $575 million ($365 million after-tax) in the second quarter of 2013. In March 2014, SCE entered into a settlement agreement with The Utility Reform Network ("TURN"), the CPUC's Office of Ratepayer Advocates ("ORA"), SDG&E, the Coalition of California Utility Employees, and Friends of the Earth (together, the "Settling Parties"). In September 2014, SCE and the Settling Parties entered into an Amended and Restated Settlement Agreement (the "San Onofre OII Settlement Agreement") which was approved by the CPUC on November 20, 2014. As a result of these developments, SCE recorded an additional pre-tax charge of approximately $163 million (approximately $72 million after-tax) during 2014. See Note 11 for further information on contingencies. 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 discussion, see Notes 9 and 10. The following table summarizes the changes in SCE's ARO liability, including San Onofre and Palo Verde:
| December 31,
(in millions) | 2014 |  | 2013
Beginning balance | $ | 3,418 |  |  | $ | 2,782 |
Accretion 1 | 192 |  |  | 182 |
Revisions | (790 | ) |  | 455 |
Liabilities settled | (1 | ) |  | (1 | )
Ending balance | $ | 2,819 |  |  | $ | 3,418 |
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.
Decommissioning costs, which are recovered through non-bypassable 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 costs of removal of its nuclear assets, and has placed those amounts in independent trusts. The cost of removal amounts, in excess of amounts collected for assets not legally required to be removed, are classified as regulatory liabilities. The recorded liability to decommission SCE's nuclear power facilities is $2.7 billion as of December 31, 2014, based on decommissioning studies performed in 2010 for Palo Verde, in 2011 for San Onofre Unit 1 and in 2014 for San Onofre Units 2 and 3 following the decision to permanently retire San Onofre. See Note 11 for further details. The San Onofre work plan developed for the revised estimate accelerated decommissioning activities beginning in 2013 from the prior assumption of 2022. In addition, certain activities that were previously forecasted to be completed at the end of the decommissioning period were accelerated over the next ten years. Although the changes in the decommissioning cost estimate for these activities in current dollars did not change significantly, the changes in timing, as well as revised escalation rates, reduced the present value of future decommissioning costs (using the 6.30% discount rate). The ARO liability related to San Onofre Units 2 and 3 decreased by $688 million in 2014 based on the updated decommissioning cost estimate. The total ARO liability related to San Onofre Units 2 and 3 at December 31, 2014 was $2.1 billion. Expenditures from June 7, 2013 through December 31, 2014 have been recorded as operation and maintenance costs and are treated as recoverable through GRC revenues, with the 2014 recorded costs being subject to customary prudency review. SCE has filed a request with the CPUC to authorize early release of nuclear decommissioning trust funds to recover SCE's share of costs from June 7, 2013 through the end of 2014. To the extent that costs are recovered from SCE's nuclear decommissioning trust as decommissioning costs, SCE intends to refund such amounts to customers as provided in the San Onofre OII Amended Settlement Agreement (as defined in Note 11). The ARO liability related to San Onofre Units 2 and 3 is lower than the present value of the decommissioning costs using current discount rates (approximately $3.0 billion at December 31, 2014). In December 2014, SCE received a decision on its 2012 NDCTP for Palo Verde and San Onofre Unit 1. The total ARO liability related to Palo Verde decreased by $253 million in 2014 and San Onofre Unit 1 increased by $124 million based on the 2012 NDCTP estimate. The changes in the decommissioning cost estimate for Palo Verde reflect the license extension of 20 years as well as revised escalation rates, which reduced the present value of future decommissioning costs (using the 4.08% discount rate). 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 $7.4 billion through 2075 to decommission its nuclear facilities. This estimate is based on SCE's decommissioning cost methodology used for ratemaking purposes, escalated at rates ranging from 1.0% to 7.3% (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 3.3% to 4.1%. If the assumed return on trust assets is not earned or costs escalate at higher rates, it is probable that additional funds needed for decommissioning will be recoverable through rates in the future. Decommissioning expense under the ratemaking method was $5 million for 2014, and $22 million in 2013 and 2012. Total expenditures for the decommissioning of San Onofre Unit 1 were $602 million from the beginning of the project in 1998 through December 31, 2014. 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 tri-annual regulatory proceeding. SCE's nuclear decommissioning trust investments primarily consist of debt 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 electric utility revenue. 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 cost 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 $201 million and $222 million at December 31, 2014 and 2013, respectively, reflected as long-term "Regulatory assets" in the consolidated balance sheets. Edison International and SCE had unamortized debt issuance costs of $83 million and $75 million at December 31, 2014, respectively, and $84 million and $79 million at December 31, 2013, respectively, reflected in "Other long-term assets" 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) | 2014 |  | 2013 |  | 2012 |  | 2014 |  | 2013 |  | 2012
Amortization of deferred financing costs charged to interest expense | $ | 36 |  |  | $ | 33 |  |  | $ | 30 |  |  | $ | 32 |  |  | $ | 32 |  |  | $ | 29 |
Revenue Recognition Revenue is recognized when electricity is delivered and includes amounts for services rendered but unbilled at the end of each reporting period and reflected in "Operating revenue" on the consolidated income statements. Rates charged to customers are based on CPUC- and FERC-authorized revenue requirements. CPUC rates are implemented subsequent to final approval. CPUC and FERC 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. 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 $134 million, $116 million and $98 million in 2014, 2013 and 2012, respectively. When SCE bills and collects taxes from customers, 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. Under this classification, the power purchase agreement is evaluated to determine if SCE is the primary beneficiary in the variable interest entity, in which case, such entity would be consolidated. None of SCE's power purchase agreements resulted in consolidation of a variable interest entity at December 31, 2014 and 2013. 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 (signed or modified after June 30, 2003) 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. These agreements are classified as operating leases as electricity is delivered at rates defined in power sales agreements. See Note 11 for further discussion of SCE's power purchase agreements, including agreements that are classified as capital leases for accounting purposes. A power purchase agreement that does not contain a lease may be classified as a derivative subject to a normal purchase and sale exception, in which case the power purchase agreement is classified as an executory contract and accounted for on an accrual basis. Most of SCE's QF contracts are not required to be recorded on the consolidated balance sheets because they either do not meet the definition of a derivative or meet the normal purchase and sale exception. SCE purchases power under certain contracts that are not eligible for the normal purchase and sale exception and are recorded as a derivative on the consolidated balance sheets at fair value. See Note 6 for further information on derivatives and hedging activities. 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. 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 expenses 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 has entered into a number of agreements to lease property and equipment in the normal course of business. Minimum lease payments under operating leases are levelized (total minimum lease payments divided by the number of years of the lease) and recorded as rent expense over the terms of the leases. Lease payments in excess of the minimum are recorded as rent expense in the year incurred. Capital leases are reported as long-term obligations on the consolidated balance sheets in "Other deferred credits and other long-term liabilities." As a rate-regulated enterprise, SCE's capital lease amortization expense and interest expense are reflected in "Purchased power and fuel" 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. Rather, a third party is used to purchase shares from the market and delivery for settlement of option exercises, performance shares and restricted stock units. Performance shares earned are settled half in cash and half in common stock; however, Edison International has discretion under certain of the awards to pay the half subject to cash settlement in common stock. Deferred stock units granted to management are settled in cash and represent a liability. 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. For awards granted to retirement-eligible participants stock compensation expenses are recognized on a prorated basis over the initial year or over the period between the date of grant and the date the participant first becomes eligible for retirement. Tax benefits related to stock-based compensation are recognized as a reduction to deferred taxes until the related tax deductions reduce current income taxes. When such event occurs, the tax benefits are then recognized through additional paid in capital. SCE allocates the tax benefits based on the provisions in the tax laws that identify the sequence in which the amounts are utilized for tax purposes. SCE Dividend Restrictions The CPUC regulates SCE's capital structure which limits the dividends it may pay Edison International. 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 weighted average basis. At December 31, 2014, SCE's 13-month weighted-average common equity component of total capitalization was 48.4% and the maximum additional dividend that SCE could pay to Edison International under this limitation was approximately $87 million. The remaining $13.2 billion of SCE's net assets are restricted. 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. EPS attributable to Edison International common shareholders was computed as follows:
| Years ended December 31,
(in millions) | 2014 |  | 2013 |  | 2012
Basic earnings per share – continuing operations: |  |  |  |  |
Income from continuing operations attributable to common shareholders | $ | 1,427 |  |  | $ | 879 |  |  | $ | 1,503 |
Participating securities dividends | (1 | ) |  | — |  |  | — |
Income from continuing operations available to common shareholders | $ | 1,426 |  |  | $ | 879 |  |  | $ | 1,503 |
Weighted average common shares outstanding | 326 |  |  | 326 |  |  | 326 |
Basic earnings per share – continuing operations | $ | 4.38 |  |  | $ | 2.70 |  |  | $ | 4.61 |
Diluted earnings per share – continuing operations: |  |  |  |  |
Income from continuing operations available to common shareholders | $ | 1,426 |  |  | $ | 879 |  |  | $ | 1,503 |
Income impact of assumed conversions | 1 |  |  | 1 |  |  | (1 | )
Income from continuing operations available to common shareholders and assumed conversions | $ | 1,427 |  |  | $ | 880 |  |  | $ | 1,502 |
Weighted average common shares outstanding | 326 |  |  | 326 |  |  | 326 |
Incremental shares from assumed conversions | 3 |  |  | 3 |  |  | 4 |
Adjusted weighted average shares – diluted | 329 |  |  | 329 |  |  | 330 |
Diluted earnings per share – continuing operations | $ | 4.33 |  |  | $ | 2.67 |  |  | $ | 4.55 |
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 125,345, 3,977,894 and 7,492,552 shares of common stock for the years ended December 31, 2014, 2013 and 2012, respectively, were outstanding, but were not included in the computation of diluted earnings per share because the exercise price of the awards was greater than the average market price of the common shares during the respective periods and, therefore, 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. 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 while production tax credits are recognized in income tax expense in the period in which they are earned. 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. Redeemable Noncontrolling Interest Redeemable noncontrolling interest represents the portion of equity ownership in an entity that is not attributable to the equity holders of Edison International and which have rights to put their ownership back to a subsidiary of Edison International. 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 rooftop projects for commercial customers are organized as limited liability companies and have a noncontrolling equity investor (referred to as tax equity investor) which is entitled to allocations of earnings, tax attributes and cash flows in accordance with contractual agreements that vary over time. This entity is consolidated for financial reporting purposes but is not subject to income taxes as the taxable income (loss) and investment tax credits are allocated to the respective owners. The total assets and liabilities of this entity consolidated at December 31, 2014 were $64 million and $39 million, respectively. Income (loss) of this entity 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 investor’s 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 ($3 million in 2014). During the third quarter of 2014, indirect subsidiaries of Edison Energy entered into three non-recourse debt and tax equity financings designed to fund significantly all of their capital requirements for approximately 35 MW solar rooftop projects. The tax equity investors in these solar rooftop projects receive 99% of taxable profits and losses and tax credits of the projects as determined for Federal income tax purposes for a six-year period following the completion of the portfolio of projects and receive a priority return of 2% of their investment per year. After the six -year period, the tax equity investor receives 5% of the taxable profits and losses and cash flow. A subsidiary of Edison International has a call option for a nine-month period following five years after completion of the portfolio of projects to purchase the tax equity investors interest at fair value as defined in the applicable agreement and the tax equity investor has the right to put its ownership interest to such subsidiary in the event that the call option is not exercised. New Accounting Guidance Accounting Guidance Not Yet Adopted On May 28, 2014, the Financial Accounting Standards Board issued an accounting standards update on revenue recognition including enhanced disclosures. Under the new standard, revenue is recognized when (or as) a good or service is transferred to the customer and the customer obtains control of the good or service. Edison International and SCE are currently evaluating this new guidance which is effective January 1, 2017 and cannot determine the impact of this standard at this time.

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