EX-99.3 4 ex993eixq22017financif0c.htm EXHIBIT 99.3 EIX Q2 2017 CONFERENCE CALL PRESENTATION DATED JULY 27, 2017
July 27, 2017 Second Quarter 2017 Financial Results Exhibit 99.3

July 27, 2017 1 Statements contained in this presentation about future performance, including, without limitation, operating results, capital expenditures, rate base growth, dividend policy, financial outlook, and other statements that are not purely historical, are forward-looking statements. These forward-looking statements reflect our current expectations; however, such statements involve risks and uncertainties. Actual results could differ materially from current expectations. These forward-looking statements represent our expectations only as of the date of this presentation, and Edison International assumes no duty to update them to reflect new information, events or circumstances. Important factors that could cause different results include, but are not limited to the: • ability of SCE to recover its costs in a timely manner from its customers through regulated rates, including costs related to San Onofre and proposed spending on grid modernization; • decisions and other actions by the CPUC, the FERC, the NRC and other regulatory authorities, including determinations of authorized rates of return or return on equity, the outcome of San Onofre CPUC proceedings, and the 2018 GRC and delays in regulatory actions; • risks associated with cost allocation, including the potential movement of costs to certain customers, caused by the ability of cities, counties and certain other public agencies to generate and/or purchase electricity for their local residents and businesses, along with other possible customer bypass or departure due to increased adoption of distributed energy resources or technological advancements in the generation, storage, transmission, distribution and use of electricity, and supported by public policy, government regulations and incentives; • risks inherent in SCE’s transmission and distribution infrastructure investment program, including those related to project site identification, public opposition, environmental mitigation, construction, permitting, power curtailment costs (payments due under power contracts in the event there is insufficient transmission to enable acceptance of power delivery), and governmental approvals; • ability to obtain sufficient insurance, including insurance relating to SCE's nuclear facilities and wildfire-related liability, and to recover the costs of such insurance or in the absence of insurance the ability to recover uninsured losses; and • risks associated with the decommissioning of San Onofre, including those related to public opposition, permitting, governmental approvals, and cost overruns. Other important factors are discussed under the headings “Risk Factors” and “Management’s Discussion and Analysis” in Edison International’s Form 10-K, most recent Form 10-Q, and other reports filed with the Securities and Exchange Commission, which are available on our website: www.edisoninvestor.com. These filings also provide additional information on historical and other factual data contained in this presentation. Forward-Looking Statements

July 27, 2017 2 Second Quarter Earnings Summary Q2 2017 Q2 2016(*) Variance Basic Earnings Per Share (EPS) SCE $ 0.94 $ 0.98 $ (0.04) EIX Parent & Other (0.09) (0.11) 0.02 Discontinued Operations — (0.01) 0.01 Basic EPS $ 0.85 $ 0.86 $ (0.01) Less: Non-core Items SCE $ — $ — $ — EIX Parent & Other1 — 0.01 (0.01) Discontinued Operations2 — (0.01) 0.01 Total Non-core $ — $ — $ — Core Earnings Per Share (EPS) SCE $ 0.94 $ 0.98 $ (0.04) EIX Parent & Other (0.09) (0.12) 0.03 Core EPS $ 0.85 $ 0.86 $ (0.01) (*) 2016 earnings was updated to reflect the implementation of the accounting standard for share-based payments effective January 1, 2016 1. Impact of hypothetical liquidation at book value (HLBV) accounting method 2. 2016 includes resolution of tax issues related to EME 3. Excludes higher income tax benefits for incremental tax repair deductions and pole-loading program-based cost of removal of $0.10 4. Excludes lower income tax benefits of $0.24 due to refunds for incremental tax benefits related to 2012-2014 repair deductions recorded in 2016 5. Excludes San Onofre revenue of ($0.01) which was offset by income taxes of $0.01 Key SCE EPS Drivers Revenue 3,4,5 $ — - CPUC - Escalation 0.11 - CPUC - Other (0.05) - FERC revenue and other (0.06) Lower O&M 0.03 Higher depreciation (0.01) Higher net financing costs (0.01) Income tax 3,4,5 $ (0.05) Total core drivers (0.04) Non-core items — Total $ (0.04) Key EIX EPS Drivers EIX parent — IRS tax settlement $ 0.02 EEG 0.01 - Buyout of an earn-out provision in 2016 0.04 - SoCore Energy goodwill impairment in 2017 (0.03) Total core drivers 0.03 Non-core items 1,2 — Total $ 0.03

July 27, 2017 3 Year to Date Earnings Summary YTD 2017 YTD 2016(*) Variance Basic Earnings Per Share (EPS) SCE $ 2.01 $ 1.88 $ 0.13 EIX Parent & Other (0.05) (0.16) 0.11 Discontinued Operations — — — Basic EPS $ 1.96 $ 1.72 $ 0.24 Less: Non-core Items SCE $ — $ — $ — EIX Parent & Other1 — 0.01 (0.01) Discontinued Operations — — — Total Non-core $ — $ 0.01 $ (0.01) Core Earnings Per Share (EPS) SCE $ 2.01 $ 1.88 $ 0.13 EIX Parent & Other (0.05) (0.17) 0.12 Core EPS $ 1.96 $ 1.71 $ 0.25 (*) 2016 earnings was updated to reflect the implementation of the accounting standard for share-based payments effective January 1, 2016 1. Impact of hypothetical liquidation at book value (HLBV) accounting method 2. Excludes higher income tax benefits for incremental tax repair deductions and pole-loading program-based cost of removal of $0.05 3. Excludes San Onofre revenue of ($0.13), interest expense of $0.01 and income taxes of $0.12. The higher income tax benefits are related to the San Onofre tax abandonment in 2017 4. Excludes lower income tax benefits of $0.24 due to refunds for incremental tax benefits related to 2012 - 2014 repair deductions in 2016 Key SCE EPS Drivers Revenue 2,3,4 $ 0.13 - CPUC - Escalation 0.21 - CPUC - Other (0.02) - FERC revenue (0.06) Lower O&M 0.09 Higher depreciation (0.05) Higher net financing costs (0.05) Income taxes 2,3,4 0.01 Total core drivers $ 0.13 Non-core items — Total $ 0.13 Key EIX EPS Drivers EIX parent — Tax benefits on stock based compensation, IRS tax settlement and other $ 0.11 EEG 0.01 - Buyout of an earn-out provision in 2016 0.04 - SoCore Energy goodwill impairment in 2017 (0.03) Total core drivers $ 0.12 Non-core items1 (0.01) Total $ 0.11

July 27, 2017 4 $4.05 $4.23(0.19)0.37 SCE 2017 EPS from Rate Base Forecast SCE Variances EIX Parent & Other EIX 2017 Core EPS Midpoint Guidance • O&M, financing and other benefits - $0.34 • Energy efficiency - $0.03 2017 Core Earnings Per Share Guidance – Building from SCE Rate Base • SCE authorized rate base $26.2 billion • Authorized CPUC capital structure - 48% equity and 10.45% ROE • FERC ROE of 10.5% • Energy efficiency earnings $0.03 per share • SONGS settlement as currently approved by CPUC • YTD incremental tax benefits included:  SCE - $0.03 per share  Holding Company - $0.09 per share • No change in tax policy • 325.8 million common shares Key Assumptions • Holding Company - ($0.08) • Edison Energy Group - ($0.08) • SoCore Impairment – ($0.03) 2017 Earnings Per Share Guidance 2017 EIX Earnings Per Share Guidance As of May 1, 2017 As of July 27, 2017 Low Mid High Low Mid High EIX Basic EPS $4.04 $4.14 $4.24 $4.13 $4.23 $4.33 Less: Non-Core Items1 - - - - - - EIX Core EPS2 $4.04 $4.14 $4.24 $4.13 $4.23 $4.33 1. There were no non-core items for the six months ended June 30, 2017 2. See Earnings Non-GAAP Reconciliations and Use of Non-GAAP Financial Measures in Appendix Updated guidance reflects strong year-to-date results, primarily related to tax benefits. We expect to continue our normal practice of updating after the third quarter for overall performance

July 27, 2017 5 SCE Capital Expenditure Forecast – Request Level Note: Forecasted capital spending includes CPUC, FERC and other spending. 2018-2020 CPUC based on 2018 GRC request rebuttal testimony. See Capital Expenditure/Rate Base Detailed Forecast for further information, including potential investment excluded in forecasts. Delta represents change from June 2017 Business Update. 1. 2016 and 2017 capital expenditures related to grid modernization are included in distribution capital expenditures ($ billions) $18.6 Billion Capital Program for 2017-2020 • Capital expenditure forecast incorporates GRC, FERC and non-GRC CPUC spending  Grid modernization spending of $1.8 billion during 2018 GRC period1  2017 traditional capital spending incorporates 2015 GRC decision and FERC spending  Includes $107 million of non-GRC CPUC capital spending for mobile home pilot program and charge ready pilot in 2017  Excludes transportation electrification and Charge Ready Phase II • Authorized/Actual may differ from forecast  Since the 2009 GRC, CPUC has approved 81%, 89%, and 92% of capital requested, respectively  SCE has no prior approval experience on grid modernization capital spending and, therefore, prior results may not be predictive  Forecasted FERC capital spending subject to timely receipt of permitting, licensing, and regulatory approvals $3.5 $3.8 $4.9 $5.0 $4.9 2016 (Actual) 2017 2018 2019 2020 Distribution Transmission Generation Traditional Capital Spending: Grid Modernization Capital Spending: Grid Modernization Prior Forecast $4.2 $4.9 $5.0 $4.9 Delta ($0.4) - - - 1

July 27, 2017 6 SCE Rate Base Forecast – Request Level CPUC • Rate base based on request levels from 2018 GRC Rebuttal Testimony and 2018 positive true-up from authorized to forecast 2017 rate base FERC • FERC rate base is approximately 20% of SCE’s rate base by 2020; includes Construction Work in Progress (CWIP) Other • No change from prior forecast • Excludes SONGS regulatory asset ($ billions) Note: Weighted-average year basis. 2016-2017 based on 2015 GRC decision. 2018-2020 CPUC based on 2018 GRC request rebuttal testimony, FERC based on latest forecast and current tax law, except “rate-base offset” for the 2015 GRC decision excluded because of write off of regulatory asset related to 2012-2014 incremental tax repairs. 4-year CAGR of 8.3% $24.9 $26.2 $29.3 $31.8 $34.3 2016 (Authorized) 2017 2018 2019 2020 Traditional Grid Modernization

July 27, 2017 7 3 4 5 6 7 10/1/12 10/1/13 10/1/14 10/1/15 10/1/16 10/1/17 10/1/18 10/1/19 R a t e ( % ) CPUC Cost of Capital CPUC Adjustment Mechanism Moody’s Baa Utility Index Spot Rate Moving Average (10/1/16 – 02/01/2017) = 4.60% 100 basis point +/- Deadband Starting Value – 5.00% Two year settlement approved • ROE adjustment based on 12-month average of Moody’s Baa utility bond rates, measured from October 1 to September 30 • If index exceeds 100 bps deadband from starting index value, authorized ROE changes by half the difference • Starting index value based on trailing 12 months of Moody’s Baa index as of September 30 of each year – 5.00% • Two year settlement approved  ROE set at 10.30%; 2018 true-up of cost of debt/preferred CPUC Authorized Settlement Terms Capital Structure 2017 2018-2019 Common Equity 48% 10.45% 10.30% Preferred 9% 5.79% TBD Long-term Debt 43% 5.49% TBD Weighted Average Cost of Capital 7.90% TBD ROE fixed at 10.30%, for 2018 independent of trigger mechanism ROE fixed at 10.45%, for 2017 independent of trigger mechanism

July 27, 2017 8 Appendix

July 27, 2017 9 2016 Retrospectively Adjusted EPS by Quarter 20161 Q4 Q3 Q2 Q1 Earnings (loss) per share attributable to Edison International Continuing Operations SCE $4.22 $1.01 $1.34 $0.98 $0.90 Edison International Parent & Other (0.23) (0.04) (0.05) (0.11) (0.04) Discontinued Operations 0.03 0.04  (0.01)  Edison International $4.02 $1.01 $1.29 $0.86 $0.86 Less: Non-Core Items SCE      Edison International Parent & Other 0.02   0.01 0.01 Discontinued Operations 0.03 0.04  (0.01)  Total Non-Core Items $0.05 $0.04   $0.01 Core Earnings (losses) SCE 4.22 1.01 1.34 0.98 0.90 Edison International Parent & Other (0.25) (0.04) (0.05) (0.12) (0.05) Edison International $3.97 $0.97 $1.29 $0.86 $0.85 1. As a result of rounding, the total of the four quarters does not always equal the amount for the year Note: Edison International and SCE adopted an accounting standard in the fourth quarter of 2016, effective January 1, 2016, which resulted in all of the tax effects related to share based payments being recorded through the income statement. Diluted EPS would have been, $1.00 for the fourth quarter of 2016, $1.27 for the third quarter of 2016, $0.85 for the second quarter of 2016 and $0.85 for the first quarter of 2016

July 27, 2017 10 Earnings Non-GAAP Reconciliations "Note: See Use of Non-GAAP Financial Measures. Earnings for second quarter and year-to-date 2016 were updated to reflect the implementation of the accounting standard for share- based payments effective January 1, 2016. ($ millions) Reconciliation of EIX GAAP Earnings to EIX Core Earnings SCE EIX Parent & Other Discontinued Operations Basic Earnings Non-Core Items SCE EIX Parent & Other Discontinued Operations Total Non-Core Core Earnings SCE EIX Parent & Other Core Earnings Earnings Attributable to Edison International $318 (36) (2) $280 $ − 2 (2) $ − $318 (38) $280 $307 (29) − $278 $ – – – $ − $307 (29) $278 Q2 2016 Q2 2017 $612 (50) (1) $561 $ − 4 (1) $3 $612 (54) $558 $656 (16) − $640 $ – 1 – $ 1 $656 (17) $639 YTD 2016 YTD 2017

July 27, 2017 11 SCE Core EPS Non-GAAP Reconciliations Basic EPS Non-Core Items Regulatory and tax items Write down, impairment and other charges Insurance recoveries Less: Total Non-Core Items Core EPS Reconciliation of SCE Basic Earnings Per Share to SCE Core Earnings Per Share 5% 5% $3.33 — — — — $3.33 $4.81 0.71 — — 0.71 $4.10 $2.76 — (1.12) — (1.12) $3.88 Note: See Use of Non-GAAP Financial Measures. $4.46 — (0.22) — (0.22) $4.68 $3.06 — (1.18) 0.04 (1.14) $4.20 Earnings Per Share Attributable to SCE CAGR2011 2012 2013 2014 2015 $4.22 — — — — $4.22 2016

July 27, 2017 12 Use of Non-GAAP Financial Measures Edison International's earnings are prepared in accordance with generally accepted accounting principles used in the United States. Management uses core earnings internally for financial planning and for analysis of performance. Core earnings are also used when communicating with investors and analysts regarding Edison International's earnings results to facilitate comparisons of the Company's performance from period to period. Core earnings are a non-GAAP financial measure and may not be comparable to those of other companies. Core earnings (or losses) are defined as earnings or losses attributable to Edison International shareholders less income or loss from discontinued operations and income or loss from significant discrete items that management does not consider representative of ongoing earnings, such as: exit activities, including sale of certain assets, and other activities that are no longer continuing; asset impairments and certain tax, regulatory or legal settlements or proceedings. A reconciliation of Non-GAAP information to GAAP information is included either on the slide where the information appears or on another slide referenced in this presentation. EIX Investor Relations Contact Sam Ramraj, Vice President (626) 302‐2540 sam.ramraj@edisonintl.com Allison Bahen, Senior Manager (626) 302‐5493 allison.bahen@edisonintl.com