EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 1 Business Update August 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 2 Statements contained in this presentation about future performance, including, without limitation, operating results, asset and rate base growth, capital expenditures, San Onofre Nuclear Generating Station (SONGS), 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 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
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 3 • One of the nation’s largest electric utilities Nearly 14 million residents in service territory Approximately 5 million customer accounts 50,000 square-mile service area • Significant infrastructure investments: 1.4 million power poles 700,000 transformers 103,000 miles of distribution and transmission lines 3,700 MW owned generation – 21% of energy to serve customers • 7 – 9% projected average annual rate base growth 2014 – 2017 driven by: System reliability and infrastructure replacement California Renewables Portfolio Standard Technology improvements SCE Highlights
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 4 SCE Decoupled Regulatory Model Decoupling of Regulated Revenues from Sales Major Balancing Accounts • Fuel • Purchased power • Energy efficiency • Pension-related contributions Advanced Long-Term Procurement Planning Forward-looking ratemaking • SCE earnings are not affected by changes in retail electricity sales • Differences between amounts collected and authorized levels are either billed or refunded to customers • Promotes energy conservation • Stabilizes revenues during economic cycles • Trigger mechanism for fuel and purchased power adjustments at 5% variance level • Utility cost-recovery via balancing accounts represented over 50% of 2013 costs • Sets prudent upfront standards allowing greater certainty of cost recovery (subject to reasonableness review) • Three-year rate case and cost of capital cycles Regulatory Model Key Benefits
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 5 $2.4 $2.9 $3.8 $3.9 $3.9 $3.5 2008 2009 2010 2011 2012 2013 SCE Historical Capital Expenditures ($ billions) Note: 2013 distribution reliability spend up $300 million, offset by completion of SmartConnect in 2012 ($300 million); lower FERC ($300 million) and lower SONGS ($100 million)
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 6 $13.1 $15.0 $16.8 $18.8 $21.0 $21.12 2008 2009 2010 2011 2012 2013 Rate Base2 Core Earnings 10% 12% 2008 – 2013 CAGR Core Earnings $2.25 $2.68 $3.01 $3.33 $4.10 SCE Historical Rate Base and Core Earnings ($ billions) $3.88 1 Recorded rate base, year-end basis. See Earnings Non-GAAP Reconciliations and Use of Non-GAAP Financial Measures in Appendix. 2 2013 rate base excludes San Onofre Generating Station (SONGS)
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 7 SCE Capital Expenditures Forecast ($ billions) 2014-17 Total Requested $4.1 $4.5 $4.4 $4.2 $17.2 Range $3.6 $3.9 $3.9 $3.7 $15.1 • Capital expenditures forecast reaffirmed • CPUC GRC focused on infrastructure replacement • Includes Tehachapi scope changes for FAA requirements and $360 million estimate for Chino Hills undergrounding $15.1 – $17.2 billion forecasted capital program 2014 – 2017 $4.1 $4.5 $4.4 $4.2 2014 2015 2016 2017 Distribution Transmission Generation Note: forecasted capital spending subject to timely receipt of permitting, licensing, and regulatory approvals. Forecast range reflects an average variability of 12%.
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 8 ($ billions) SCE Rate Base Forecast • Growth rate reaffirmed • Driven by infrastructure replacement, reliability investments, and public policy requirements • FERC rate base includes CWIP and is approximately 22% of 2014 rate base forecast, increasing to 24% in 2017 • Excludes SONGS rate base 7 – 9% CAGR projected rate base 2014 – 2017 Requested Range $21.9 $23.4 $25.5 $27.1 $22.4 $24.4 $27.0 $29.2 2014 2015 2016 2017 Note: Weighted-average year basis, including forecasted 2014 FERC and 2015-2017 CPUC rate base requests and consolidation of FERC CWIP projects. Rate Base forecast range reflects capital expenditure forecast range.
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 9 Distribution ($ millions) SCE System Investments Transmission • Large transmission projects: Tehachapi – $3.2 billion total project cost; 2016-17 in service date Coolwater-Lugo – $0.8 billion total project cost; 2018 in service date West of Devers – $1.0 billion total project cost; 2019-20 in service date • Aging system reaching equilibrium replacement rate • 2015 GRC request includes ~120% increase in infrastructure replacement 2015 – 2017 Requested GRC Expenditures for Distribution Assets $9.3 Billion Load Growth New Service Connections Infrastructure Replacement General Plant1 Other Note: Total Project Costs are nominal direct expenditures, subject to CPUC and FERC cost recovery approval
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 10 SCE Growth Drivers Beyond 2017 Infrastructure Reliability Investment • Sustained level of infrastructure investment required until equilibrium replacement rates are achieved - includes underground cable, poles, switches, and transformers1 Grid Readiness • Accelerate automation and control technology at optimal locations to manage two-way power flows with more dynamic voltage control • Distribution Resource Plan required under AB 327 to identify optimal locations, additional spending, and barriers to deploying distributed energy resources – due to CPUC Q3 2015 Transmission • California ISO 2013-2014 Transmission Plan2 - approved Mesa Loop-in Project (system reliability post-SONGS and renewables integration) with target in-service date of December 31, 2020 • Two existing projects incorporated from prior Transmission Plans in service beyond 2017 include Coolwater-Lugo (2018) and West of Devers (2019-2020) Energy Storage • 290 MW utility owned investment opportunity 2015-2024 Future Potential California Public Policy Requirements and Enabling Projects • Transportation electrification • Renewables mandates beyond 33% 1 Source: A.13-11-0032015 GRC – SCE-01 Policy testimony; equilibrium replacement rate defined as equipment population divided by mean time to failure for type of equipment 2 Approved by the California ISO Board of Governors March 20, 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 11 SCE 2015 CPUC General Rate Case • November 2013, 2015 GRC Application A.13-11-003 filed March 2014, Scoping Memo issued, schedule revised July 21st Supplemental testimony, ordered by May 15th Assigned Commissions Ruling, on risk management and safety matters submitted July 3rd • Request sets base revenue requirement for 2015 – 2017 Includes operating costs and CPUC jurisdictional capital Excludes fuel and purchased power (and other utility cost-recovery activities), cost of capital, and FERC jurisdictional transmission • 2015 revenue requirement request of $5.860 billion, after removing SONGS and Four Corners in April 2014 $227 million increase over presently authorized base rates (excluding SONGS) Post test year requested increase of $321 million in 2016 and additional increase of $330 million in 2017 • Request consistent with SCE strategy to ramp up infrastructure investment consistent with capital plan while mitigating customer rate impacts through productivity and lower operating costs • The current CPUC schedule does not specify a proposed decision timeframe but will likely be in 2015 Nov 12 GRC Application Aug 18 Intervenor Testimony Sept 29 Evidentiary Hearings 2013 2014 Feb 11 Prehearing Conference Jan 14-15 Update Hearing 2015 Aug 4 ORA Testimony Nov 25 Opening Briefs Dec 11 Reply Briefs
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 12 CPUC and FERC Cost of Capital • CPUC – 48% equity with 10.45% ROE and adjustment mechanism approved through 2015 Weighted average authorized cost of capital – 7.90% ROE adjustment based on 12-month average of Moody’s Baa utility bond rates, measured from Oct. 1 to Sept. 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, 2012 – 5.00% SCE will submit new application in April 2015 for Cost of Capital in 2016 • FERC – November 2013 settlement 10.45% ROE comprised of: 9.30% base + 50 bps CAISO participation + 65 bps weighted average for project incentives Moratorium on filing ROE changes through June 30, 2015 FERC Formula recovery mechanism in effect through 2017 3 4 5 6 7 10/1/12 10/1/13 10/1/14 10/1/15 Ra te (% ) CPUC Adjustment Mechanism Moody’s Baa Utility Index Spot Rate Moving Average (10/1/13 – 7/16/14) = 4.99% 100 basis point +/- Deadband Starting Value – 5.00%
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 13 SCE Key Regulatory Events Calendar Rate Design OIR (R.12-06-013) 2015 GRC (A.13-11-003) 2H 2014 1H 2015 2H 2015 2016 SONGS Settlement (I.12-10-013) Other proceedings next steps: • CAISO 2013-2014 Transmission Plan – Board approval of Delaney-Colorado economic line in September 2014; project subject to FERC Order 1000 competitive bidding. • 2012 Long Term Procurement Plan (LTPP) Track 1 Local Capacity Requirements (LCR) – Total 1,400 to 1,800 MW preferred resources, gas-fired, energy storage to replace Once-Through-Cooling units, and Track 4 to replace SONGS authorizes 500 to 700 MW to be online by 2022, final selection on October 16, 2014. • Energy Storage OIR – First procurement cycle December 2014. SCE targeting net 14 MW storage capacity, excluding 74 MW existing and LCR storage. July – Revised Scoping Memo Aug – ORA testimony Sept - Evidentiary Hearings Sept – NEM Scoping Memo Fall – NEM proposed decision TBD – Proposed Decision Cost of Capital April – Initial Filing New Cost of Capital takes effect Spring – Fixed charge and tiers proposed decision Jan – Update Hearing
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 14 2014 Core and Basic Earnings Guidance Key Assumptions: • Midpoint rate base of $22.1 billion • Approved capital structure – 48% equity, 10.45% CPUC & FERC ROE • 325.8 million common shares outstanding (no change) • No significant transmission project delays Other Assumptions: • No change in tax policy • O&M cost savings flow through to ratepayers in 2015 GRC • Excludes $0.56 per share non-core item recorded in Q2 2014 but not in guidance • Excludes $0.23 per share core items (uncertain tax position and other tax benefits, additional FERC revenue and FERC energy settlements) included in YTD 2014 results but not in guidance 2014 Earnings Guidance as of 4/29/14 Low Mid High SCE $3.85 EIX Parent & Other (0.15) EIX Core EPS 1 $3.60 $3.70 $3.80 Non-core Items 2 (0.36) EIX Basic EPS $3.24 $3.34 $3.44 $3.40 $(0.07) $0.52 $(0.15) $3.70 SCE 2014 EPS from Rate Base Forecast SONGS Shutdown SCE 2014 Positive Variances EIX Parent & Other 2014 Midpoint Guidance • Cost savings / other - $0.35 • Income taxes - $0.14 • Energy efficiency earnings - $0.03 • SONGS LT Debt & Pf dividends Year to date earnings are trending above the high end of the guidance range and guidance may be adjusted when third quarter earnings are reported 1 See Use of Non-GAAP Financial Measures in Appendix 2 Represents non-core items recorded for the three months ended March 31, 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 15 $1.22 $1.24 $1.26 $1.28 $1.30 $1.35 $1.42 $2.25 $2.68 $3.01 $3.33 $4.10 $3.88 $3.85 $0.00 $1.00 $2.00 $3.00 $4.00 $5.00 2008 2009 2010 2011 2012 2013 2014 SCE Core EPS EIX Dividend Paid (37%) EIX Dividend Growth In December, EIX increased its dividend for the 10th consecutive year to an annual rate of $1.42 per share for 2014 • EIX targets paying out 45 – 55% of SCE earnings • Dividend growth rate slowed to help fund large utility capital program, which is plateauing • EIX plans to return to target dividend range over time SCE Core EPS EIX Dividend 12% 2% 2008 – 2013 CAGR (32%) (38%) (42%) (46%) (54%) (35%) Guidance Midpoint Note: See Use of Non-GAAP Financial Measures in Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 16 Creating Shareholder Value Resolve Uncertainties Create Sustainable Earnings and Dividend Growth Position for Transformative Sector Change • SCE 2013 cost of capital • SCE 2012 FERC formula rate settlement • EME restructuring • SONGS OII settlement reached • 10% 5-year SCE rate base CAGR (2008 – 2013) • 12% Core SCE EPS growth (2008 – 2013) • 10 consecutive years of EIX dividend increases • Acquired SoCore Energy (commercial solar) • Minority investments (energy efficiency, residential solar markets, transportation electrification) • SONGS OII settlement approval • SONGS third-party cost recovery • Monetize EME tax benefits • SCE 2015 GRC • Execute wires-focused investment program • 7 – 9% projected rate base growth (2014 – 2017) • Optimize cost structure through operational excellence • Return to target dividend range over time • Rate reform – AB 327 implementation • Evaluate new power sector business opportunities W ha t W e’v e Do ne W ha t Re ma ins Note: See use of Non-GAAP Financial Measures in Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 17 EIX is Responding to Industry Change • Public policy prioritizing environmental sustainability • Innovation facilitating conservation and self- generation • Regulation supporting new forms of competition • Flattening domestic demand for electricity • Grid of the future will be more complex and sophisticated to support increasing use of distributed resources and transportation electrification • SCE Strategy Invest in, build, and operate the next generation electric grid Operational and service excellence Enable California public policies • EIX Competitive Strategy – small, targeted investments in emerging technologies and markets to follow changes in the industry and better exploit opportunities as they arise Commercial and industrial distributed generation Energy optimization Energy efficiency and software Residential solar industry financial services and software Electric transportation Long-Term Industry Trends Strategy
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 18 Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 19 Changes Since Our Last Presentation • Quarterly updates • SCE Growth Drivers Beyond 2017 (p. 10) – new slide • SCE 2015 CPUC General Rate Case (p. 11) • SCE Key Regulatory Events Calendar (p. 13) – new slide • 2014 Core and Basic Earnings Guidance (p. 14) • EIX is Responding to Industry Change (p. 17) – new slide • SCE 2014 Bundled Revenue Requirement (p. 20) – new slide • Residential Rate Design OIR (p. 22) • SCE Residential Net Metering Rate Structure (p. 23) • Solar Installations in SCE Service Territory (p. 24) – new slide • New Technology Grid Impacts (p. 28) – new slide • California Renewables Policy (p. 30) • SCE Rates and Bills Comparison (p. 32) • SONGS Settlement – Accounting (p. 41) • SONGS Third-Party Recovery – NEIL Insurance (p. 44) • SONGS – Units 2 and 3 Decommissioning (p. 45)
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 20 SCE 2014 Bundled Revenue Requirement 2014 Bundled Revenue Requirement $millions ¢/kWh Fuel & Purchased Power – includes CDWR Bond Charge 5,071 6.9 Distribution – poles, wires, substations, service centers; Edison SmartConnect® 3,867 5.3 Generation – utility owned generation investment and O&M 2,048 2.8 Transmission – greater than 220kV 735 1.0 Other – CPUC and legislative public purpose programs, system reliability investments, nuclear decommissioning 539 0.7 Total Bundled Revenue Requirement ($millions) $12,260 Bundled kWh (millions) 73,249 = Bundled Systemwide Average Rate (¢/kWh) 16.7¢ Approximately 60% of SCE’s revenue requirement consists of utility earnings activities: distribution, generation, and transmission Fuel & Purchased Power (41%) Distribution (32%) Transmission (6%) Generation (17%) Other (4%) Note: Rates in effect as of July 7, 2014, based on forecast. Represents bundled service which excludes Direct Access customers that do not receive generation services.
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 21 Kilowatt-Hour Sales (millions of kWh) Residential Commercial Industrial Public authorities Agricultural and other Resale Total Kilowatt-Hour Sales Customers Residential Commercial Industrial Public authorities Agricultural Railroads and railways Interdepartmental Total Number of Customers Number of New Connections Area Peak Demand (MW) SCE Customer Demand Trends 2012 30,563 40,541 8,504 5,196 1,676 1,735 88,215 4,321,171 549,855 10,922 46,493 21,917 83 24 4,950,465 22,866 21,981 2011 29,631 39,622 8,490 5,206 1,318 3,071 87,338 4,301,969 546,936 11,370 46,684 22,086 82 22 4,929,149 19,829 22,374 2010 29,034 39,318 8,507 5,336 1,353 4,103 87,651 4,285,803 543,016 11,708 46,718 22,321 73 23 4,909,662 25,566 22,771 2009 30,078 40,076 8,522 5,686 1,499 5,869 91,730 4,262,966 539,270 12,244 46,902 22,315 67 23 4,883,787 32,145 22,112 2013 29,889 40,649 8,472 5,012 1,885 1,490 87,397 4,344,429 554,592 10,584 46,323 21,679 99 23 4,977,729 27,370 22,534 Note: See Edison International Financial and Statistical Reports for further information
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 22 Residential Rate Design OIR 14.85 19.28 28.10 32.10 0 5 10 15 20 25 30 35 0 200 400 600 800 1,000 1,200 1,400 ¢/ kW h kWh/month SCE Proposed 2018 Tiers: • Two tiers: Tier 1 – 16.4¢/kWh Tier 2 – 19.7¢/kWh • June 2012, CPUC opened Order Instituting Rulemaking (OIR) R.12-06-013: Comprehensive review of residential rate structure Transition to Time of Use (TOU) rates AB327 rate design • Phase 2 (Summer 2014): simple tiered rate adjustments Settlement approved in June; rates implemented in July – 12% increase to Tier 1 rate, 17% increase to Tier 2 rate • Phase 1 (2015 – 2018): longer-term rates 2 tiers (2017); TOU rates (2018) Fixed charge or minimum bill (2015) Proposed Decision expected March 2015 • Net Energy Metering 20-year grandfathering of current NEM tariff only for existing customers and new installations up to 5% cap (2,240 MW for SCE) Successor tariff Q4 2015 Tier 1 Tier 2 Tier 3 Tier 4 OIR Phase 2 Settlement Summary Fixed Monthly Charge Current: $0.94/month SCE Proposed: $10/month
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 23 SCE Residential Net Metering Rate Structure 8.7¢ 30.6¢21.9¢ 0 5 10 15 20 25 30 35 ¢/ kW h Solar Subsidies (Illustrative) Generation Rate Subsidy Paid by Other Ratepayers Equivalent Solar Rate Current rate design results in residential solar customers receiving a subsidy funded by all other non-solar customers in higher tiers • Residential solar customer generation offsets total retail rate • Average retail rate of 30.6¢/kWh vs. actual generation cost of 8.7¢/kWh • Resulting 21.9¢/kWh is a subsidy funded by all other non-solar customers in Tiers 3 and 4 SCE 2013 Net Energy Metering Statistics: • 76,400 combined residential and non- residential customers – 697 MW installed 99.5% solar 73,300 residential – 361 MW 3,100 non-residential – 336 MW • Approximately 1,000,000 mWh / year generated, or 1% of total sales Note: Based on average home usage of 1,150 kWh/month, a 4-tier rate structure, and a 4.8kW solar system with a 18% capacity factor that generates 631 kWh per month
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 24 Solar Installations in SCE Service Territory – 5,000 10,000 15,000 20,000 25,000 30,000 – 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 Jan -09 Ma r-0 9 Ma y-0 9 Jul -09 Se p-0 9 No v-0 9 Jan -10 Ma r-1 0 Ma y-1 0 Jul -10 Se p-1 0 No v-1 0 Jan -11 Ma r-1 1 Ma y-1 1 Jul -11 Se p-1 1 No v-1 1 Jan -12 Ma r-1 2 Ma y-1 2 Jul -12 Se p-1 2 No v-1 2 Jan -13 Ma r-1 3 Ma y-1 3 Jul -13 Se p-1 3 No v-1 3 Jan -14 Ma r-1 4 Ma y-1 4 Nu mb er of In sta lla tio ns kW In sta lle d Number of Installations kW Installed Note: NEM solar installations in SCE service territory include projects with solar PV only less than 1 MW
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 25 Rooftop Solar – Grid Interaction 0.0 0.5 1.0 1.5 2.0 2.5 3.0 3.5 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 Ki low at t Time of Day Typical Residential Rooftop Solar Customer Profile1,2 Solar Production Consumption SCE Provides Power Customer generation, grid support needed Customer uses grid to export excess power SCE Provides Power Summer Solar customers benefit from the flexibility provided by the SCE grid 1 Solar production shape based on a 4.8 kW system expected summer performance (source: https://sam.nrel.gov/). Sizing to eliminate Tier 3 and 4 usage. 2 Residential consumption shape based on summer average for a high user (1,150 kWh/month) (source: SCE load research)
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 26 All Generation Cost Trends, Unsubsidized $0.149 $0.109 $0.065 $0.061 $0.086 $0.089 $0.045 $0.123 $0.067 $0.108 $0.144 $0.086 $0.000 $0.050 $0.100 $0.150 $0.200 $0.250 Solar PV (Distributed) Fuel Cell Coal Gas (CCGT) Nuclear Solar PV (Utility Scale) Wind (Utility Scale) Lazard 2012 Levelized Cost of Energy (range) EIA 2012 Levelized Cost of Energy $0.087 $0.122 $0.095 $0.204 $0.206 $0.145 $0.104$/ kW h Distributed Generation Central Station / Utility Scale Generation Levelized cost of energy for distributed generation resources continues to move toward equilibrium with other generation sources Sources: Lazard Levelized Cost of Energy Version 7.0 August 2013; EIA Levelized Cost of Energy Analysis 2013
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 27 Energy Storage • AB2514 directed CPUC to establish procurement targets and policies for storage • CPUC final decision in Energy Storage OIR (R.10-12-007) 1,325 MW target for IOUs by 2024 (580 MW SCE share) Three types: transmission (53%), distribution (32%), customer-sited (15%) Utility ownership limited to 50% of total target (290 MW SCE share) First standalone procurement cycle in December 2014 − Existing storage and prior RFO storage expected to count for ~74MW of SCE’s 90 MW target Broad range of technologies as defined in AB2514, excluding large hydro (>50 MW) SCE 2014 Existing Storage SCE’s energy storage investment opportunities will focus on distribution grid projects and will be integrated into future capital expenditure requests • Tehachapi Storage Project • Irvine Smart Grid Demonstration Projects • Large Energy Storage Test Apparatus • Discovery Science Center • Catalina Island Battery System • Vehicle-to-Grid Program – LA Air Force Base • Self-Generation Incentive Program • Permanent Load Shifting Program 13.68 16.40 50 30 10 Transmission Distribution Customer MW 2014 Existing Eligible Storage 2014 Storage Target
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 28 2 1 1 3 1 1 1 2 2 New Technology Grid Impacts Future state based on evolving energy landscape More automated and digital, with more sophisticated voltage control and protection schemes Facilitates increasing renewables & two-way power flow Cyber mitigation must be included 1 2 3
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 29 California Climate Change Policy • Assembly Bill 32 (2006) – reduces State greenhouse gas (GHG) emissions to 1990 levels by 2020 (~16% reduction) • Cap and trade program basics: State-wide cap in 2013 – decreases over time Compliance met through allowances, offsets, or emissions reductions Excess allowances sold, or “banked” for future use January 2014 – merger with Quebec cap and trade program • SCE received 32.3 million 2013 allowances vs. 10.4 million metric tons 2012 GHG emissions • Allowances sold into quarterly auction and bought back for compliance SB 1018 (2012) – auction revenues used for rate relief for residential (~93%), small business, and large industrial customers AB32 Emissions Reduction Programs Cap & Trade 22% Other 23% Low Carbon Fuel Standard 19% RPS 14% Energy Efficiency 15% High GWP Gases 7%
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 30 California Renewables Policy • On April 12, 2011, Governor Brown signed SB X 1 2, which codifies a 33% Renewables Portfolio Standard (RPS) for California by 2020 Allows use of Renewable Energy Credits (RECs) for up to 25% of target with decreasing percentages over time Applies similar RPS rules to all electricity providers (investor- and publicly-owned utilities, as well as Electric Service Providers) • In order to meet the 33% RPS requirement by 2020, SCE will increase its renewable purchases by 10 billion kWh, or 60% While SCE is on track to meet the 33% renewables target by 2020, the requirement will put upward pressure on customer rates Solar 7% Small Hydro 2% Geothermal 41% Biomass 3% Wind 47% Actual 2013 Renewable Resources: 21.6% of SCE’s portfolio
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 31 SCE Energy Efficiency Programs 1.7 1.6 1.1 0.9 2011 2012 2013 2014 Energy efficiency programs updated for 2013 – 2014 • SCE is a national leader 2012 energy savings = 1.8% of retail sales1 • 2014 budget of $352 million2 • Target 0.9 billion kWh average annual savings for 2013-14 cycle3 – Reduced goals reflect CPUC-identified market potential for energy efficiency Annual kWh Savings (billions) Energy efficiency earnings incentive mechanism modified • New earnings mechanism for 2011, 2012 (payable in 2013, 2014) – 5% management fee + up to 1% performance bonus • December 2013, $13.5 million awarded for 2011 program year – additional $5 million pending results of 2014 energy efficiency programs audit • SCE to file earnings claim for 2012 and part of 2013 program activity this year – actual payment, if any, subject to CPUC approval • CPUC approved new incentive mechanism for 2013 and 2014 activities (payable in 2014 and beyond) comprised of performance rewards and management fees Future Directions • SCE is identifying opportunities, such as SCE’s Preferred Resources Pilot, to leverage EE and other demand side resources to meet grid reliability needs. 1 Does not include resale sales. Energy savings subject to ex-post CPUC review. 2 Excludes income qualified energy efficiency and integrated demand-side management program funding authorizations for 2013 3 Based on CPUC goals established for SCE. Market potential changes in response to program funding levels, customer participation assumptions, market influences and the implementation of new building codes and minimum appliance efficiency standards
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 32 12.6 16.6 US Average SCE 33% Higher SCE Rates and Bills Comparison • SCE’s residential rates are above national average due, in part, to a cleaner fuel mix – cost for renewables are higher than high carbon sources • Average monthly residential bills are lower than national average – higher rate levels offset by lower usage 55% lower SCE residential customer usage than national average, from mild climate and higher energy efficiency building standards • Public policy mandates (33% RPS, AB32 GHG, Once-through Cooling) and electric system requirements will drive rates and bills higher 2014 Average Residential Rates (¢/kWh) 2014 Average Residential Bills ($ per Month) Key Factors ¢ ¢ SCE’s average residential rates are above national average, but residential bills are below national average due to lower energy usage $126 $75 US Average SCE 40% Lower Source: EIA's Form 826 Data Monthly Electric Utility Sales and Revenue Data for the Data 12 Months Ending April 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 33 Coastal Power Plants Local Reliability Areas (generalized) California Transmission System (partial, generalized) CA Once Through Cooling Policy – Legend • Short-term SONGS closure solutions Transmission – 220 kV Barre-Ellis reconfiguration Voltage support – Huntington Beach 3 and 4 synchronous condensers Substations – Santiago, Viejo, Johanna capacitor bank upgrades Generation – El Segundo repower (550 MW), Sentinel (728 MW), Walnut Creek (480 MW) Conservation – EE, demand response, Flex Alerts • Long-term issues Once-through cooling – approximately 6,000 MW affected in SCE territory Air quality and emissions – limitations on permits, cap and trade market Distributed generation and renewables – integration, flexibility and net load SCE System Reliability
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 34 Second Quarter Earnings Summary Q2 2014 Q2 2013 Variance Core EPS1 SCE $1.11 $0.84 $0.27 EIX Parent & Other (0.03) (0.05) 0.02 Core EPS1 $1.08 $0.79 $0.29 Non-Core Items SCE $– $(1.12) $1.12 EIX Parent & Other – – – Discontinued Operations 0.56 0.04 0.52 Total Non-Core $0.56 $(1.08) $1.64 Basic EPS $1.64 $(0.29) $1.93 Diluted EPS $1.63 $(0.29) $1.92 SCE Key Core Earnings Drivers Higher revenue $0.17 SONGS impact 0.03 Higher O&M2 (0.02) Higher depreciation (0.05) Higher net financing costs (0.02) Income taxes and other 0.16 - Changes in uncertain tax positions 0.09 - Other tax benefits 0.04 - Generator settlements 0.03 Total $0.27 EIX Key Core Earnings Drivers Higher tax benefits $0.03 Costs of new businesses (0.01) Total $0.02 1 See Earnings Non-GAAP Reconciliations and Use of Non-GAAP Financial Measures in Appendix 2 Includes non-SONGS severance of $0.01 and $0.02 for the three months ended June 30 of 2014 and 2013, respectively
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 35 Year-to-Date Earnings Summary YTD 2014 YTD 2013 Variance Core EPS1 SCE $2.04 $1.63 $0.41 EIX Parent & Other (0.06) (0.06) 0.00 Core EPS1 $1.98 $1.57 $0.41 Non-Core Items SCE $(0.29) $(1.12) $0.83 EIX Parent & Other – 0.02 (0.02) Discontinued Operations 0.49 0.07 0.42 Total Non-Core $0.20 $(1.03) $1.23 Basic EPS $2.18 $0.54 $1.64 Diluted EPS $2.17 $0.54 $1.63 EIX Key Core Earnings Drivers Higher tax benefits $0.01 Costs of new businesses (0.01) Total $0.00 SCE Key Core Earnings Drivers Higher revenue $0.31 SONGS impact 0.02 Lower O&M2 0.05 Higher depreciation (0.12) Higher net financing costs (0.05) Income taxes and other 0.20 - Changes in uncertain tax positions 0.09 - Other tax benefits 0.08 - Generator settlements 0.03 Total $0.41 1 See Earnings Non-GAAP Reconciliations and Use of Non-GAAP Financial Measures in Appendix 2 Includes non-SONGS severance of $0.01 and $0.05 for the six months ended June 30, 2014 and 2013, respectively
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 36 Earnings Non-GAAP Reconciliations ($ millions) Reconciliation of EIX Core Earnings to EIX GAAP Earnings Earnings Attributable to Edison International Core Earnings SCE EIX Parent & Other Core Earnings Non-Core Items SCE EIX Parent & Other Discontinued operations Total Non-Core Basic Earnings Q22013 $274 (15) $259 $(365) – 12 (353) $(94) Q22014 $362 (10) $352 $– – 184 184 $536 YTD2013 $530 (20) $510 $(365) 7 24 (334) $176 YTD2014 $666 (20) $646 $(96) – 162 66 $712 Note: See Use of Non-GAAP Financial Measures in Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 37 Earnings Per Share Attributable to SCE Core EPS Non-Core Items Tax settlement Health care legislation Regulatory and tax items Asset impairment Total Non-Core Items Basic EPS SCE Core EPS Non-GAAP Reconciliations Reconciliation of SCE Core Earnings Per Share to SCE Basic Earnings Per Share 2008 $2.25 — — (0.15) — (0.15) $2.10 2009 $2.68 0.94 — 0.14 — 1.08 $3.76 2010 $3.01 0.30 (0.12) — — 0.18 $3.19 CAGR 12% 6% 2011 $3.33 — — — — — $3.33 2012 $4.10 — — 0.71 — 0.71 $4.81 2013 $3.88 — — — (1.12) (1.12) $2.76 Note: See Use of Non-GAAP Financial Measures in Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 38 $6,682 — 2,518 1,562 296 32 4,408 2,274 94 (494) 1,874 214 1,660 91 $1,569 $5,169 4,139 1,026 — (1) — 5,164 5 — (5) — — — — $— $6,602 — 2,348 1,622 307 575 4,852 1,750 48 (519) 1,279 279 1,000 100 $900 $5,960 4,891 1,068 — — — 5,959 1 — (1) — — — — $— $12,562 4,891 3,416 1,622 307 575 10,811 1,751 48 (520) 1,279 279 1,000 100 $900 $1,265 (365) $900 SCE Results of Operations ($ millions) Utility Earning Activities Utility Cost- Recovery Activities Total Consolidated 2013 Utility Earning Activities Utility Cost- Recovery Activities Total Consolidated 2012 Operating revenue Fuel and purchased power Operation and maintenance Depreciation, decommissioning and amortization Property and other taxes Asset impairment and disallowances Total operating expenses Operating income Interest income and other Interest expense Income before income taxes Income tax expense Net income Preferred and preference stock requirements Net income available for common stock Core earnings Non-core earnings Total SCE GAAP earnings $11,851 4,139 3,544 1,562 295 32 9,572 2,279 94 (499) 1,874 214 1,660 91 $1,569 $1,338 231 $1,569 • Utility earning activities – revenue authorized by CPUC and FERC to provide reasonable cost recovery and return on investment • Utility cost-recovery activities – CPUC- and FERC-authorized balancing accounts to recover specific project or program costs, subject to reasonableness review or compliance with upfront standards Note: See Use of Non-GAAP Financial Measures in Appendix
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 39 SONGS Settlement – Summary Term Description Steam Generators • Steam Generator Replacement Project (“SGRP”) removed from rates as of February 1, 2012, with book value balance disallowed. Revenues related to the SGRP collected after February 1, 2012, refunded to customers. Power Costs • Full recovery of replacement power costs Regulatory Asset Recovery • Non SGRP plant costs are recovered in rates over 10 years from February 1, 2012 • Weighted average return equal to authorized cost on debt and 50% of authorized cost on preferred; no return on equity. Results in current weighted average return of 2.62%. • Construction Work in Progress (CWIP) and materials and supplies are recovered with same return over same period • Nuclear Fuel amortized over same period; return at customary commercial paper rate • 5% of proceeds of any sales / dispositions of materials, supplies, and nuclear fuel accrue to shareholders, as well as 5% reduction in nuclear fuel commitments • Regulatory Asset can be removed from ratemaking capital structure, thus reducing equity requirement in excess of $300 million Operations & Maintenance Costs • Recorded O&M for 2013 recovered, including incremental inspection and repair costs • O&M recovery for 2012 limited to CPUC authorized amounts • Leaves $99 million incremental inspection and repair costs not recovered in rates (these costs were previously expensed) Sharing of SCE Recovery Proceeds • NEIL: 82.5% ratepayers / 17.5% Shareholders • MHI: Shareholders receive 85% of first $100 million; 2/3 of next $800 million; and 1/4 of amounts above $900 million • Litigation costs recovered before sharing starts
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 40 NEIL • Credit to ERRA MHI • First $282 million – credit to General Rate Case Base Revenue Requirement Balancing Account (BRRBA) • Above $282 million – reduce SONGS regulatory asset • Credit to BRRBA after full SONGS regulatory asset recovered SONGS Settlement – Third-Party Recoveries NEIL All 17.5% MHI • First $100 million 85% • Next $800 million 66.67% • Above $900 million 25% SCE Share Non-Core Earnings Customer Share NEIL All 82.5% MHI • First $100 million 15% • Next $800 million 33.33% • Above $900 million 75% • SCE’s share of recoveries from NEIL and MHI will be allocated between SCE and customers • Litigation fees recovered prior to SCE / customer sharing
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 41 SONGS Settlement – Accounting • Q2 2013, SCE recorded $575 million pre-tax and $365 million after-tax impairment based on management’s judgment of the recoverability of SONGS investment Developed based on a range of possible outcomes Each quarter, management must assess recoverability • Q1 2014, SCE increased its total pre-tax impairment by $231 million to a total of $806 million (after-tax increase of $96 million to a total of $461 million) based on terms of Settlement Primary drivers of impairment charge: Disallowance of SGRP investment – $542 million as of May 31, 2013 Refund of revenues related to SGRP previously recognized – $159 million Implementation of other terms of the Settlement Agreement, including refund of authorized return in excess of the return allowed for non-SGRP investments Refund of revenues to customers from flow-through tax benefits – increases effective tax rate • If approved, the settlement would result in a core earnings benefit of approximately $0.03 per share in 2014 and $0.04 per share annually, declining over 10 years • SCE has not recorded a receivable for potential recoveries from either MHI or NEIL SCE recorded an additional pre-tax impairment of $231 million ($96 million after-tax, or $0.29 per share) in Q1 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 42 SONGS Settlement – Regulatory Asset Category December 31, 20131 June 30, 2014 Authorized Return Base Plant $488 2.62% SGRP - n/a CWIP2 $2,166 403 2.62% Materials and Supplies 78 2.62% Nuclear Fuel 407 Commercial Paper Rate Asset Impairment (575) (5) n/a Regulatory Asset $1,591 $1,371 Estimated Revenue Refund Authorized revenue in excess of recorded (266) (483) As of June 30, 2014, SONGS regulatory assets under the Settlement Agreement are $1.4 billion, with recovery expected through January 31, 2022 ($ millions) 1 December 31, 2013, balance of $2,166 million comprised of $2,096 million net investment at May 31, 2013, plus $70 million of costs recorded thereafter. Individual components not disclosed. 2 CWIP includes both completed and cancelled CWIP as defined by the Settlement Agreement
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 43 SONGS Third-Party Recovery – MHI Warranty Summary Request for Arbitration • 20-year warranty: Repair or replace defective items Specified damages for certain repairs $138 million liability limit and exclusion for consequential damages (e.g. replacement power) Limits subject to applicable exceptions in the contract and under law • 7 invoices submitted totaling $149 million for repair costs through April 30, 2013 First invoice of $45 million ($36 million SCE share) paid, subject to audit, reservation of rights regarding documentation • October 2013, Request for Arbitration filed with the International Chamber of Commerce per MHI contract • Claims for damages consistent with July 2013 Notice of Dispute that was unsuccessfully resolved with MHI • Exceptions to damage limitations are argued to apply: Direct Damages – $138 million warranty cap does not apply due to, among other things, gross negligence Consequential Damages – contract waiver does not apply due to, among other things, “failure of essential purpose” • MHI responded in December 2013 countering SCE’s claims and asserting $41 million in counterclaims SCE’s position is that the steam generator tube leak and resulting damages represent a total and fundamental failure of performance by MHI
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 44 SONGS Third-Party Recovery – NEIL Insurance • Accidental property damage and accidental outage insurance through Nuclear Electric Insurance Limited (“NEIL”) Accidental Property Damage Policies – $2.5 million deductible; $2.75 billion liability limit Accidental Outage Policy – weekly indemnity up to $3.5 million per unit after 12-week deductible period ($2.8 million per unit per week if both are out due to same “accident”); $490 million limit per unit ($392 million each if both units are out due to the same “accident”) Exclusions and limitations may reduce or eliminate coverage Proof of loss must be submitted within 12 months of damage or outage • Accidental outage policy benefits are reduced to: 80% of weekly indemnity after 52 weeks; and 10% of weekly indemnity after early retirement announcement • Separate proofs of loss have been filed for Unit 2 and Unit 3 under NEIL accidental outage policy totaling $414 million ($325 million SCE share) for amounts through February 22, 2014 SCE is continuing to make weekly indemnity claims post-shutdown decision at 10% value per the terms of the policy SCE has not submitted a proof of loss under the accidental property damage policies – SCE has received an extension to file such a claim to December 31, 2014 • NEIL may make a coverage determination by end of Q3 2014, but it may take longer
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 45 SONGS – Units 2 and 3 Decommissioning Decommissioning Trusts • Decommissioning Trust contributions recovered in rates approved by CPUC in triennial proceeding • Updated site-specific decommissioning cost study estimate (2014 dollars, all owners): $4.4 billion, or $106 million less than previous estimate SCE share of decommissioning costs is $3.3 billion (2014 dollars), or $2.9 billion (after cost escalation and discounting) SCE nuclear decommissioning trust funds total $3.1 billion after estimated taxes, or 104% funded • No additional nuclear decommissioning trust fund contributions are needed at this time Decommissioning Process • June 2013, Certification of Permanent Cessation of Power Operations submitted to NRC • All initial decommissioning activity phase plans and cost estimates will be provided by end of 2014 • Decommissioning involves three related activities: radiological decommissioning, non-radiological decommissioning and management of spent nuclear fuel • Access to the decommissioning trusts requires an order from the CPUC. SCE’s advice letter requesting interim access is pending before the commission.
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 46 EME Bankruptcy Settlement Implementation • April 2014, amended Plan of Reorganization completed • EME emerged from bankruptcy and remains subsidiary of EIX Consolidated for tax purposes • Reorganization Trust established to receive tax benefit payments from EIX Cash Impact • Based on the preliminary estimate: EIX expects net benefits of approximately $232 million EIX expects to utilize approximately $1.2 billion of EME tax benefits – 50% to Reorganization Trust EIX would make an estimated $634 million in total payments through 2016 (including interest): o $225 million paid April 1, 2014 o $199 million on September 30, 2015 o $210 million on September 30, 2016 • Deferred payment amounts to be finalized by the end of 2014 Accounting Treatment • Approximately $48 million of net benefits recorded as non-core income through March 31, 2014 • Balance of net benefits of $184 million was recorded as non-core income in Q2 2014
EDISON INTERNATIONAL® Leading the Way in Electricity SM August 1, 2014 47 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. Use of Non-GAAP Financial Measures EIX Investor Relations Contacts Scott Cunningham, Vice President (626) 302-2540 scott.cunningham@edisonintl.com Felicia Williams, Senior Manager (626) 302-5493 felicia.williams@edisonintl.com
