Exhibit 99.1

Business Update February 25 , 2022

1 Statements contained in this presentation about future performance, including, without limitation, operating results, capital ex penditures, rate base growth, dividend policy, financial outlook, and other statements that are not purely historical, are forward - looking statements. These forward - looking statements r eflect our current expectations; however, such statements involve risks and uncertainties. Actual results could differ materially from current expectations. These forward - looking stateme nts 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. Im por tant factors that could cause different results include, but are not limited to the: • ability of SCE to recover its costs through regulated rates, including uninsured wildfire - related and debris flow - related costs , costs incurred to mitigate the risk of utility equipment causing future wildfires, costs incurred to implement SCE's new customer service system, costs incurred as a result of the CO VID - 19 pandemic, and increased labor and materials costs due to supply chain constraints and inflation; • ability of SCE to implement its Wildfire Mitigation Plan and capital program; • risks of regulatory or legislative restrictions that would limit SCE’s ability to implement Public Safety Power Shutoff (“PSP S”) when conditions warrant or would otherwise limit SCE’s operational PSPS practices; • risks associated with implementing PSPS, including regulatory fines and penalties, claims for damages and reputational harm; • ability of SCE to maintain a valid safety certification; • ability to obtain sufficient insurance at a reasonable cost, including insurance relating to SCE's nuclear facilities and wil dfi re - related claims, and to recover the costs of such insurance or, in the event liabilities exceed insured amounts, the ability to recover uninsured losses from customers or other parties; • extreme weather - related incidents (including events caused, or exacerbated, by climate change, such as wildfires, debris flows, droughts, high wind events and extreme heat events) and other natural disasters (such as earthquakes), which could cause, among other things, public safety issues, property damage, ope rational issues (such as rotating outages and issues due to damaged infrastructure), PSPS activations and unanticipated costs; • risk that California Assembly Bill 1054 (“AB 1054”) does not effectively mitigate the significant exposure faced by Californi a i nvestor - owned utilities related to liability for damages arising from catastrophic wildfires where utility facilities are alleged to be a substantial cause, including the longevity o f t he Wildfire Insurance Fund and the CPUC's interpretation of and actions under AB 1054, including its interpretation of the prudency standard established under AB 1054; • ability of Edison International and SCE to effectively attract, manage, develop and retain a skilled workforce, including its co ntract workers; • decisions and other actions by the California Public Utilities Commission, the Federal Energy Regulatory Commission, the Nucl ear Regulatory Commission and other governmental authorities, including decisions and actions related to nationwide or statewide crisis, determinations of authorized rates of re turn or return on equity, the recoverability of wildfire - related and debris flow - related costs, issuance of SCE's wildfire safety certification, wildfire mitigation efforts, approval an d implementation of electrification programs, and delays in executive, regulatory and legislative actions; • ability of Edison International or SCE to borrow funds and access bank and capital markets on reasonable terms; • risks associated with the decommissioning of San Onofre, including those related to worker and public safety, public oppositi on, permitting, governmental approvals, on - site storage of spent nuclear fuel, delays, contractual disputes, and cost overruns; • pandemics, such as COVID - 19, and other events that cause regional, statewide, national or global disruption, which could impact, among other things, Edison International's and SCE's business, operations, cash flows, liquidity and/or financial results and cause Edison International and SCE to incur unantici pat ed costs; • physical security of Edison International's and SCE's critical assets and personnel and the cybersecurity of Edison Internati ona l's and SCE's critical information technology systems for grid control, and business, employee and customer data; • risks associated with cost allocation resulting in higher rates for utility bundled service customers because of possible cus tom er bypass or departure for other electricity providers such as Community Choice Aggregators (“CCA,” which are cities, counties, and certain other public agencies with the authority to g ene rate and/or purchase electricity for their local residents and businesses) and Electric Service Providers (entities that offer electric power and ancillary services to retail customers , o ther than electrical corporations (like SCE) and CCAs); • risks inherent in SCE’s capital investment program, including those related to project site identification, public opposition , e nvironmental mitigation, construction, permitting, changes in the California Independent System Operator’s transmission plans, and governmental approvals; and • risks associated with the operation of electrical facilities, including worker and public safety issues, the risk of utility ass ets causing or contributing to wildfires, failure, availability, efficiency, and output of equipment and facilities, and availability and cost of spare parts. Other important factors are discussed under the headings “Forward - Looking Statements”, “Risk Factors” and “Management’s Discussi on and Analysis” in Edison International’s Form 10 - K and other reports filed with the Securities and Exchange Commission, which are available on our website: www.edisoninvestor.c om. These filings also provide additional information on historical and other factual data contained in this presentation. Forward - Looking Statements February 25, 2022

2 Edison International is leading the transformation of the electric power industry One of the nation’s largest electric - only utilities, serving over 15 million residents EIX’s principal subsidiary, with ~$5+ billion annual electric infrastructure investment opportunity Growth driven by investment in strengthening and modernizing the grid and advancing California’s aggressive climate goals Wires - focused rate base of ~$39 billion, with limited ownership of power generation capacity (<20% of power delivered from owned generation) Provides integrated decarbonization and energy solutions to commercial, institutional and industrial customers Customer base includes 22 of the Fortune 100 Holding company focused on opportunities in clean energy, efficient electrification, grid of the future, and customer choice February 25, 2022

3 EIX is well positioned for a decarbonized future, with no coal or gas LDC exposure and high electric sales growth potential UTY 1 EEI Index 2 Electric - Only & No Gas LDC Exposure (# of Companies) 6 of 20 12 of 39 ✓ No stranded asset risk with increased electrification No Coal Generation Ownership (# of Companies) 5 of 20 9 of 39 ✓ No coal generation or contracts in SCE’s portfolio 100% Carbon - free Electricity by 2045 3,4 (# of Companies) 5 of 20 14 of 39 ✓ SCE’s aggressive target is strongly aligned with California’s net zero goal Electric Sales per Customer (MWh/year) 5 13 – 38 Avg: 24 12 – 53 Avg: 24 16 Relatively low per - customer usage will grow with electrification, which supports affordability 1. Philadelphia Utilities Index (UTY) consists of 20 geographically diverse public utility stocks, including one water utility. Val ues shown include EIX 2. EEI Index consists of 39 publicly traded companies that are members of Edison Electric Institute, which includes 18 of the co mpa nies also in UTY. Values shown include EIX 3. Company counts reflect the number of companies with goals of net zero or carbon - free electricity targets by 2045 or sooner 4. For EIX, defined as 100% carbon - free electricity delivered to SCE customers in terms of retail sales by 2045 5. Based on latest available data for year ended 2020 Source: EIX research, S&P Capital IQ Pro February 25, 2022

4 Sustainability is central to Edison’s vision to lead the transformation of the electric power industry Social Environmental Governance 2045 goals: net - zero GHG emissions across Scopes 1, 2, and 3 and 100% carbon - free power delivered ( ~42% in 2021) 1 Over $800 million in approved SCE funding to expand transportation electrification SCE named to SEPA 2021 Utility Transformation Leaderboard for progress toward carbon - free grid Winner of EEI’s Edison Award for innovative suite of Transportation Electrification programs Committed to SCE vehicle fleet electrification goals by 2030 Highest level governance score from ISS Board oversight of ESG risks such as safety, climate change impacts, and cybersecurity 8 of 12 directors diverse by gender, race/ethnicity, and/or LGBTQ, including 5 women 3 50% of executive annual incentive pay tied to safety & resiliency - related goals for 2022 Recognized as a CPA - Zicklin “Trendsetter” in political accountability and disclosure 4 Recipient of several awards for workplace diversity & inclusion 2 Long - standing community partnerships , incl. $2.4B annual spend with diverse suppliers Publish expansive data 2 on workforce, supplier, and community investment diversity Committed to gender parity in executive roles by 2030 and broader DEI actions $20 million per year in philanthropic contributions with at least 80% going to diverse and underserved communities We are committed to achieving net - zero GHG emissions by 2045 and have other long - term ESG goals related to clean energy, electrification, DE&I, and safety 1. Net zero goal is enterprise - wide. Delivered power goal is SCE - specific and percentages refer to power delivered to SCE customers . Reflects no coal generation of delivered electricity 2. View data in our annual Diversity, Equity & Inclusion Report, as well as awards and recognition in our annual Sustainability Rep ort, both found on our Sustainability site 3. In April 2022, William P. Sullivan is expected to retire from the Board, at which point 8 of 11 directors will be diverse, in clu ding 5 women 4. Edison International is recognized as a “Trendsetter” on the Center for Public Accountability (“CPA”) - Zicklin Index of Corporate Political Disclosure and Accountability. The Trendsetter category highlights leaders in the S&P 500 for commitments to transparency and accountability in political spending February 25, 2022

5 Our sustainable financing activities underscore the strong link between our strategy and financings February 25, 2022 Primary Category 1 U.N. Sustainable Development Goals Alignment Green Renewable Energy Clean Transportation Energy Efficiency & Carbon Reduction Climate Change Adaptation Social Socioeconomic Advancement and Empowerment, Including Gender Inclusion Green, Social, and Sustainability instruments will fund projects that provide distinct environmental or social benefits Eligible Project Categorie s Included in Sustainable Financing Framework 1. Excludes projects with GHG intensity above 100 gCO2e / kWh and bioenergy projects that do not have a sustainable feedstock (i .e. , does not negatively impact food security or contribute to deforestation). Excludes any expenditures on fossil fuel - fired generation, nuclear generation or large hydro (>30 MW) 2. Vigeo Eiris was acquired by Moody’s Corporation in 2019 and has rebranded as Moody’s ESG Solutions since providing their seco nd - party opinion 3. Issued independent of Edison’s Sustainable Financing Framework; Vigeo Eiris separately provided an additional second - party opini on on offerings alignment with ICMA’s Green Bond Principles Edison’s Sustainable Financing Framework aligned with ICMA’s Green Bond Principles, Social Bond Principles, and Sustainability Bond Guidelines Vigeo Eiris 2 , second - party opinion provider, rated framework’s Contribution to Sustainability as “Advanced” (highest rating) SCE has issued $2.1 billion of sustainable bonds for eligible projects under the framework and $0.5 billion of green securitization bonds 3

6 Thesis: Wires - focused electric utility with regulated rate base growth aligned with state’s aggressive clean energy goals Constructive California and Federal regulatory structures Aggressive climate goals met with clean, efficient, economy - wide electrification Significant investment required to strengthen and modernize the electric grid Investment in electric - led clean energy future results in strong rate base and dividend growth Decoupling of sales Forward - looking ratemaking Premium California ROE Wildfire prudency standard California GHG reduction Helping customers make clean energy choices Address wildfire risk and climate adaptation needs Infrastructure replacement Electrification infrastructure 7 – 9% average annual 2021 – 2025 rate base growth Target dividend payout of 45 – 55% of SCE core earnings February 25, 2022

7 California’s regulatory mechanisms provide revenue certainty, even as load and payment patterns change Revenue Decoupling means earnings aren’t affected by changes in electricity sales Long - standing regulatory mechanism that breaks the link between retail electricity sales and revenue; promotes energy efficiency, helps stabilize customer bills, and supports environmental goals Changes in sales only affect timing of cash collection Balancing Accounts allow SCE to collect and refund differences to authorized revenue SCE has several balancing accounts, including for variances in sales volume, such as those related to COVID - 19 Balancing account established for residential uncollectibles COVID - 19 Related Memo Accounts allow SCE to track cost and payment changes for cost recovery requests CPUC approved COVID - 19 Pandemic Protections Memo Account (CPPMA) where SCE tracks non - payment of billed amounts for residential and small business customers 1 CPUC approved establishment of Medium - Large Commercial and Industrial memo account to track incremental costs of disconnection moratorium on these customers and related uncollectibles Eligible COVID - 19 - related costs record to CEMA Each requires seeking approval to recover costs recorded to them 1. Residential bad debt expense records to the Residential Uncollectibles Balancing Account (RUBA) (not the CPPMA) and does not req uire additional approval before recovering in rates February 25, 2022

CLEAN ENERGY TRANSITION LEADERSHIP

9 Reaching California’s 2045 GHG goals requires a near - complete transformation of energy use economy wide February 25, 2022 100% of grid sales with carbon - free electricity 80 GW of utility - scale clean generation 30 GW of utility - scale energy storage 30 GW of generation and 10 GW of storage from DERs, including 50% of single - family homes 30% of space and water heating to be electrified by 2030 70% of space and water heating to be electrified by 2045 Building electrification will increase load significantly by 2045 — representing 15% of the total load 76% of light - duty vehicles need to be electric 67% of medium - duty vehicles need to be electric 38% of heavy - duty vehicles need to be electric Natural gas capacity provides a crucial role for reliability and affordability; however, consumption will decline 50% by 2045 40% of remaining gas will need to be low carbon fuels (e.g., biomethane, hydrogen) Pathway 2045: Key steps California must take to reach carbon neutrality Edison will continue working in partnership with state and federal governments and with other stakeholders, including the communities we serve, to advance policies that rapidly cut GHG emissions Sequestration can be achieved through additional natural resources or engineered solutions Emerging technologies and practices will be required to find the most economical method to remove carbon at this scale

10 Electricity sales required to be 100% carbon - free by 2045 Decarbonizing transportation sector, ~40% of GHG emissions, requires widespread vehicle electrification State’s commitment highlighted by requiring all new passenger vehicles sold to be zero - emission by 2035 and operations of MD/HD vehicles 2 be zero - emission by 2045 Electrification of buildings and industrial processes also a key factor Remaining emissions require offset or sequestration to reach carbon neutrality 1. Buildings and Other includes residential, commercial, and agriculture 2. Medium - and heavy - duty (MD/HD) vehicles shall be 100% zero - emission by 2045 where feasible, with the mandate going into effect b y 2035 for drayage trucks Source: SCE’s Pathway 2045 analysis SCE is a catalyst for achieving California’s aggressive GHG and clean energy goals via economy - wide electrification Achieving 80% GHG reduction by 2050 will require fuel use changes in all sectors State Carbon Emissions Reduction Pathway California GHG Emissions, Annual million metric tons (MMT) – 100 200 300 400 2015 2020 2025 2030 2035 2040 2045 2050 80% by 2050 ( 86 MMT ) Carbon Neutrality by 2045 (108 MMT) 40% by 2030 ( 260 MMT ) Electricity Transportation Industrial Buildings and Other 1 February 25, 2022

11 Significant incremental grid investments required by 2045 to serve load growth and integrate renewables and storage February 25, 2022 1. In 2019 dollars under Balanced Scenario 2. Source: CAISO Draft 20 - year Transmission Outlook published January 31, 2022, which is long - range conceptual plan of the transmis sion grid in 20 years to provide context for and framing of issues in CAISO’s 10 - year Transmission Plan. The 20 - year outlook is not a tariff - based project approval process that focuses on project ap provals 3. SCE estimates that CAISO’s Draft 20 - year Transmission Outlook includes approximately $8 billion of transmission investments in t he utility’s service area, which may be competitively bid Source: SCE’s Pathway 2045 analysis. See Pathway 2045 Appendices for additional information on the analysis and its methodolo gy CAISO Grid Investment 2031 – 2045 At least a third of incremental grid investment fits squarely within IOU jurisdictions CAISO - wide grid investment in Pathway 2045 Balanced Scenario ~$75 billion (2019$) Transmission for Out - of - State Imports ISO Interconnections Local Capacity Distribution Subtransmission Infrastructure to interconnect and integrate resources May be mix of investment by utilities, generators, and other market participants Utility infrastructure additions and upgrades Predominantly investments by utilities in their service areas CAISO - wide investment required at various voltage levels and to address specific system needs CAISO estimates $30 billion of transmission investment needed through 2040 2 ; generally consistent with SCE’s Pathway 2045 analysis 3 Upgrades at lower voltages are clearly utility - owned; transmission projects may be competitively bid Potential additional utility investment upside from storage – Pathway 2045 analysis showed ~$54 billion 1 need for battery storage CAISO - wide – May be opportunities where utilities are natural owners

12 Annual residential household energy costs (2019$) 1 2019 2045 By 2045, a greater reliance on electricity, combined with population and economic growth, will result in a 60% increase in electricity sales from the grid Household savings driven by reduced gasoline consumption due to high market penetration of electric vehicles Improvements in equipment efficiency, energy efficiency, and demand response programs further reduce consumption Total energy cost for an average household decreases by about one - third by 2045 A decarbonized, electrified world produces energy cost savings for an average household $3,130 $4,550 Home Solar Electricity Bill Home Gas Bill Gasoline 1. Reflects annual energy costs using SCE data and does not account for the cost of equipment. Assumes average customer in 2045 wou ld have electric vehicle, solar, and electric water and space heating Source: SCE’s Pathway 2045 analysis February 25, 2022

13 SCE’s average rate has grown less than inflation over the last 20 years, even with recent increases to mitigate wildfire risks February 25, 2022 22.3 25.1 28.0 SCE PG&E SDG&E 1. All rates include California Climate Credit 2. Inflation data based on CPI Los Angeles - Long Beach - Anaheim region: through December 31, 2021 Sources: SCE Advice 4651 - E/A effective Jan. 1, 2022, PG&E Advice 6408 - E - B effective Jan. 1, 2022, SDG&E Advice 3881 - E effective Jan. 1, 2022 Among California IOUs, SCE has the lowest system average rate System Average Rate 1 Cents per kWh 10 15 20 25 2001 '06 '11 '16 2021 SCE System Average Rate Los Angeles Area Inflation SCE’s system average rate has grown at an annualized ~2.3% vs. local inflation of ~2.6% since 2001 2 Cents per kWh +13% vs SCE +26% vs SCE

14 Transportation Electrification Energy Storage Edison International has one of the strongest electrification profiles in the industry February 25, 2022 Building Electrification 1. As of December 2021. Source: DMV on data provided by EPRI 2. Based on SCE analysis. SCE’s Pathway 2045 analysis estimates that 7.5 million light - duty EVs are needed by 2030 for California t o meet its decarbonization target Largest U.S. IOU EV charging programs with over $800 million of approved funding Substantial state budget commitments to accelerate zero - emission vehicles 1 in 7 U.S. EVs are in SCE’s service area 1 Current trajectory of 4.7 million EVs in CA (1.7 million in SCE’s area) by 2030, and need to achieve 7.5 million 2 Represents ~6.7 million MWh of incremental load in SCE’s area by 2030 and ~50 million MWh by 2045 SCE recently proposed $677 million plan to accelerate adoption of 250,000 heat pumps State’s proposed $962 million investment in building decarbonization complements SCE’s plan Target to have 20 million residential heat pumps in California by 2045 Represents ~2.2 million MWh of incremental load in SCE’s area by 2030 ~9.8 million MWh by 2045 SCE has installed or procured ~3.2 GW of storage capacity SCE constructing ~535 MW of utility - owned storage to support reliability Project 30 GW of utility - scale storage needed California - wide by 2045 Growing energy storage capacity supports reliability as economy increasingly relies on electricity

15 $872 $414 $367 $235 $205 $205 EIX PCG ED SRE PEG NEE SCE leads the largest utility transportation electrification initiatives and programs in the U.S. 1. Low Carbon Fuel Standard. The LCFS program at the California Air Resources Board (CARB) funds SCE’s vehicle rebate programs t hro ugh the sale of LCFS credits to market participants and not through customer rates. These amounts are distinct from funding approved for SCE’s transportation electrification programs Sources: EEI Electric Transportation Biannual State Regulatory Update (November 2021), SCE Edison’s large suite of TE programs enables California’s leadership of EV adoption Approved Electric Utility Transportation Electrification Portfolios >$200 Million; $ in Millions (capital and O&M) By 2030, SCE will administer over $1 billion of EV purchase incentives and other equity focused programs funded via California’s LCFS program 1 By 2027, SCE’s offerings will have: – Added >40,000 light - duty vehicle chargers and ~8,500 medium - and heavy - duty vehicles – Directly contributed to electrification of >550,000 vehicles with ~50% in disadvantaged communities EIX/SCE received the prestigious EEI Edison Award for SCE’s innovative suite of TE programs February 25, 2022

16 SCE’s future load growth is highly levered to EV adoption, which is a critical component of reaching state GHG goals 1. Includes both light duty and non - light duty EV load 2. As of December 2021. Source: DMV data provided by EPRI To date, ~1 in 7 U.S. electric vehicles have been sold in SCE’s service area 2 – ~330,000 EVs in SCE’s area 2 SCE’s Charge Ready programs are expected to stimulate growth in EV adoption and the build out of charging infrastructure SCE’s programs include a focus on serving multi - family unit dwellings and disadvantaged communities Proposed state budget funding of $10 billion to accelerate zero - emission vehicles represents significant progress in helping spur adoption Electric vehicles in SCE’s service area added ~2,250 GWh of load in 2021 and could grow to 50,000+ GWh by 2045 Electric load from electric vehicles in SCE’s service area, GWh 1 February 25, 2022 0 10,000 20,000 30,000 40,000 50,000 60,000 2020 '25 '30 '35 '40 2045 Current Trajectory Pathway 2045 Trajectory More durable funding for transportation market required to close the gap

17 Increased energy storage is essential to support the transition to a carbon - free future – 1,000 2,000 3,000 4,000 5,000 6,000 7,000 2020 2021 2022 2023 2024 2025 2026 Future Procurement Requirements Procured or Under Construction Online 1. SCE’s proportional procurement obligation under D.21 - 06 - 035 SCE is in the process of procuring 2,800 MW for 2023 and 2024 CPUC mid - term reliability decision requires SCE to procure ~3,706 MW of energy storage to be online 2023 through 2026 and ~350 MW of baseload renewables (e.g., geothermal) by 2026 1 SCE constructing ~535 MW of utility - owned storage on track to be in service by August 2022 to help alleviate reliability risks SCE estimates that California will need 10 GW of utility - scale energy storage by 2030 and 30 GW by 2045 to support the transition to 100% carbon - free power SCE has installed or procured ~3.2 GW of storage capacity and must procure ~3.2 GW more by 2026 1 Energy storage capacity procured and online (MW) February 25, 2022

SCE WILDFIRE MITIGATION: APPROACH, PROGRESS, AND RESULTS

19 AB 1054 1 provides a strong regulatory construct for determining wildfire liability and cost recovery February 25, 2022 Established safety certification process and additional wildfire safety oversight Under AB 1054, SCE can obtain an annual safety certification upon submission of required safety information, including an approved wildfire mitigation plan Safety certifications valid for 12 months and remain valid until CPUC Wildfire Safety Division acts on SCE’s request for a new safety certification Codified prudency standard that assumes utility prudency unless serious doubt created Provided a utility is “safety certified,” establishes a prudency standard that assumes utility is prudent, unless intervenors create serious doubt Prudency based on reasonable utility conduct with potential for full or partial recovery, considering factors within and beyond a utility’s control (e.g., humidity, temperature, winds) Standard survives even if Wildfire Insurance Fund is depleted Established ~$21 billion Wildfire Insurance Fund Enhances liquidity available to pay wildfire claims Reimburses utility for eligible claims payments above the higher of $1 billion and required insurance coverage Caps utility liability exposure if utility found imprudent (SCE 2022 cap: ~$3.4Bn) If found prudent, no requirement to reimburse fund for claims covered by fund If found imprudent or partially imprudent, shareholders reimburse fund. Reimbursement capped if utility has valid safety certification 2 . The c ap covers trailing three - year period and limits reimbursement to 20% of electric T&D equity rate base 3 1. California Assembly Bill 1054, executed by the governor of California on July 12, 2019 2. And has not been found to have acted with conscious or willful disregard of the rights and safety of others 3. Excluding general plant and intangibles

20 • Pay out claims to claimants subject to fund administrator approval • Subrogation claims settled at ≤40% approved unless exceptional facts and circumstances; higher amounts may be approved by fund administrator Fund payment of “eligible claims” 4 AB 1054 and the Wildfire Insurance Fund provide clear pathway to determine IOU’s prudency and ceiling on liability CPUC prudency d e t e r mi nat i on of operations (serious doubt standard) 1. This summary is based on Edison International’s interpretation of Assembly Bill 1054 2. Range based on whether customer charge finances DWR bonds or is contributed directly to Wildfire Fund 3. Source: California Earthquake Authority Financial Report presented at the January 27, 2022 California Catastrophe Response Co unc il meeting 4. “Eligible claims”: claims for third - party damages from covered wildfires less annual utility retention (larger of $1.0 billion o r required insurance layer per fund administrator) 5. Excluding general plant and intangibles February 25, 2022 AB 1054 Wildfire Insurance Fund Mechanics 1 • “Covered Wildfire” means any wildfire ignited on or after July 12, 2019, caused by an electrical corporation as determined by the governmental agency responsible for determining causation, in excess of annual utility retention • Size of fund equal to $21.0 – 24.0 billion 2 . Currently, fund has ~$10 billion in assets as of November 30, 2021 3 • Funds invested / managed by California Earthquake Authority (CEA) • Fund reimbursed if imprudent (see below right), but does not have a separate replenishment mechanism Wildfire Insurance Fund • Liability cap of 20% of T&D Equity Rate Base 5 (~$3.4 Bn for SCE for 2022) unless found to have acted with conscious or willful disregard • Liability cap lapses when fund exhausted If found imprudent, IOU reimburses Wildfire Fund up to 3 - year rolling cap If found prudent, IOU does not reimburse Wildfire Fund PG&E: $4.8Bn initial + $193MM annually through 2028 SCE: $2.4Bn initial + $95MM annually through 2028 SDG&E: $0.3Bn initial + $13MM annually through 2028 IOUs contribute $10.5 billion Customers contribute $0.9Bn annually through 2035. May be directly contributed to Fund or used to support issuance of up to $10.5Bn in bonds by California DWR Customers contribute non - bypassable charge

21 Wildfire Fund Illustrated: Eligible claims paid by Fund and IOUs reimburse up to cap only to degree found imprudent 1,2 February 25, 2022 SCE does not reimburse Fund for eligible claims 1 above annual aggregate retention of $1 billion If found 100% prudent 2 SCE’s Insurance/ Retention Wildfire Insurance Fund Utility Shareholders 1. Eligible claims are those that exceed the greater of $1 billion or the amount of the utility's wildfire insurance as required by the Fund administrator. Liability cap applies unless SCE is found to have acted with a conscious or willful disregard of the rights and safety of others 2. Costs in application may be allocated for cost recovery in full or in part considering factors within and beyond utility’s contr ol, including humidity, temperature, and winds 3. Claims typically settle at a percentage of the asserted damages 1.0 4.0 1.0 0.6 3.4 If found 100% imprudent 2 $5 billion cost of paid claims 3 (Wildfire Fund reimburses utility for claims paid above IOU retention) SCE cost recovery application and CPUC review Example of Wildfire Insurance Fund operations, reimbursement, and IOU liability from a hypothetical wildfire resulting in $5 billion of paid claims $ in Billions; Example based on SCE’s 2022 Liability Cap Liability cap (20% of T&D equity rate base) reduced by IOU reimbursement on 3 - year rolling basis for subsequent events 2 $5.0 $5.0

22 Many of SCE’s wildfire mitigation practices have been in place for years and have greatly evolved since 2018 February 25, 2022 Longstanding wildfire mitigation efforts at SCE Pre - 2018 practices and enhancements Foundational strategy established in 2018 – 2019 GS&RP (2018) and 2019 WMP Advance technology and risk modeling capabilities 2020 WMP & 2021 WMP Update Update of long - term system hardening strategy 2022 WMP Update Fire prevention planning - Special procedures for Red Flag Warnings - Automated recloser (RAR) blocking on fire weather days Engineering and design - RARs installed to sectionalize grid - Principles to reduce possibility of debris contacting equipment Veg. mgmt. and other inspection programs Standard operating practices, emergency planning & response, and outreach activities during a wildfire event Grid hardening - Covered conductor - Fire resistant poles - Current limiting fuses - Additional RAR installations Bolstering situational awareness capabilities - HD cameras - Weather stations Enhancing operational practices - Extra - sensitive (“fast curve”) relay settings - PSPS operational enhancements - Expanded line clearances and new hazard tree program Improving wildfire risk assessments & models - Analytical granularity - Transition to Technosylva fire spread model Inspection strategy evolution - Expanded inspections based on emergent fuel conditions Continued minimizing of PSPS impacts - Sectionalization - Customer care programs Aerial fire suppression Advancing new technologies - Open Phase Detection - Rapid Earth Fault Current Limiter - Early Fault Detection Expanded grid hardening - Updated risk analysis for covered conductor deployment & targeted undergrounding Updating veg. mgmt. risk prioritization - Tree risk index - Risk prioritized pole brushing methodology Continued reduction of PSPS impacts Adding new mitigation strategies - Transmission wires down - Vibration dampeners - Secondary conductor ignitions - Additional customer care pilots

23 https://players.brightcove.net/979328848001/ default_default/index.html?videoId=6142883 567001 https://fsapps.nwcg.gov/psp/sawti https://www.sce.com/weatherstatio ns http://www.alertwildfire.org/orang ecoca/index.html Publicly available real - time data enhances situational awareness and informs critical operational decisions Live HD camera feeds provide critical information to fire agencies for effectively deploying air and ground resources Provide real - time weather data, including wind speed and gust, temperature, and humidity Enables circuit - level monitoring to inform critical operational decisions Helps fire agencies and the public prepare for a wildfire threat during a high wind event Users can see this information in real - time to help understand threat of wind - driven wildfires Cameras on ALERT Wildfire Network HD Weather Stations Santa Ana Wildfire Threat Index Cameras Weather Stations Threat Index RELATED LINKS FOR VIEWING EOC Virtual Tour Emergency Operations Center (EOC) SCE’s Emergency Operations Center acts as the company’s nerve center for 24/7 planning and emergency response February 25, 2022

24 https://library.sce.com/conten t/dam/eix/documents/investo rs/wildfires - document - library/Wildfire_CaliforniaBiom es.pdf Covered conductor is one of the most effective measures to reduce wildfire and PSPS risks in SCE’s service area February 25, 2022 Execution Speed Geography Unique Factors Cost to Implement ~ 1.5 ~ 5.5 ~ 0.6 Under- ground Covered Conductor Undergrounding is considered where there is: • High burn frequency • Limited egress • Wind speeds exceeding covered conductor PSPS thresholds • Exceptionally high potential consequence (>10,000 acres) Covered conductor can be deployed within 16 – 24+ months, and sometimes faster Undergrounding generally takes 25 – 36+ months Covered conductor installation costs significantly lower than undergrounding Undergrounding costs vary depending on construction methods, locational, and operational factors Contact from vegetation and other objects is a key risk factor in much of SCE’s area Covered conductor is very effective in mitigating these risks 1. Based on data provided in SCE’s 2022 WMP Update 2. Through December 31, 2021 3. Undergrounded miles is a hypothetical approximation of underground lines that could have been constructed through December 31 , 2 021, based on SCE’s assumptions and experience with planning and executing undergrounding projects Covered conductor is a very valuable tool to expeditiously and cost - effectively reduce wildfire risk specific to SCE. Undergrounding considered for certain locations based on risk profile Cost per mile 1 $ in Millions Chaparral (brushland) presents different primary risk factors than heavily forested areas ~65 – 90% lower Click to view larger image Vegetation Type Evergreen Forest Deciduous Forest Broadleaved Forest Chaparral Grassland Desert Scrub Actual installed miles of covered conductor 2 vs. hypothetical undergrounded miles 3 ~A few Hundred Covered Conductor Under - ground ~2,900+ Several hundred miles currently under consideration for additional enhanced mitigation, including undergrounding

25 California has continued to increase investments in wildfire suppression and prevention 1 February 25, 2022 CAL FIRE budget support along with actions to increase staffing and improve effectiveness ~$2.5 – 2.8bn/year ~7,180 – 8,769 Increases to firefighting crews Helicopter fleet replacement Air tanker funding Advanced modeling and analytics to inform suppression strategy Surge capacity New wildfire cameras and communications equipment deployed Fuel reduction projects $1.5 billion Wildfire & Forest Resilience Strategy 3 ~$3.7bn ~10,050 Additional firefighters Helicopter acquisition completion Air asset expansion Wildfire & Forest Resilience Strategy ( Add’l . $1.2bn across depts. and years 3 ) Resilient Forests & Landscapes Wildfire Fuel Breaks Reforestation Regional Investments Community Hardening Science - Based Management Forest Sector Stimulus Substantial increase in wildfire suppression budget to address shifting risk factors Governor’s proposed budget would increase funding to support firefighters, equipment and forest mgmt. 2016 - 17 & 2017 - 18 Budget Years 2018 - 19 through 2020 - 22 Budget Years 2022 - 23 Budget Year CAL FIRE Budget 2 : ~$2.0bn/year CAL FIRE Positions: ~6,900 Extended peak staffing period Began procurement process to replace helicopters to enhance initial attack effectiveness Additional year - round engines 1. Total state funding and resources for wildfire suppression and prevention are also reflected in budgets of other departments, co unties, and the State Mutual Aid System 2. As initially enacted. Does not include subsequent Emergency Fund funding. 2022 - 23 Budget refers to the Governor’s Proposed Budge t 3. Budgeted across departments and budget years. Composed of $536 million in 2020 - 21, $988 million in 2021 - 2022. The additional $1. 2 billion proposed in the 2022 - 23 budget includes spending during budget years 2022 - 23 and 2023 - 24. Portions of the funding for the Wildfire & Forest Resilience Strategy are captured with in CAL FIRE’s overall budget and the action in this reference

26 SCE’s execution of its wildfire mitigation strategy is reducing risk of wildfires associated with utility infrastructure February 25, 2022 Note: Data as of December 31, 2021. Blue check marks indicate met or exceeded target Hazard Tree Management target was adjusted from 150,000 to 120,000. Pending Q4 change order approval from Office of Energy In fra structure Safety Community Resource Centers Community Crew Vehicles 64 sites available 8 vehicles available High - Definition Wildfire Cameras Completed Since 2018 166 cameras installed Cameras currently provide visibility to about 90% of our high fire risk areas (HFRA) and the planned additional cameras in 2022 and beyond will increase coverage to nearly all of HFRA Distribution Equipment Inspections 2021 Completed/Target 179,600/163,000 inspections Completed Since 2018 764,000+ inspections Transmission Equipment Inspections 2021 Completed/Target 20,800/16,800 inspections Completed Since 2018 106,900 + inspections Insulated Wire (Covered Conductor) 2021 Completed/Target 1,500/1,000 circuit miles installed Completed Since 2018 2,900+ circuit miles installed Fast - Acting Fuses 2021 Completed/Target 350/330 fuses installed or replaced Completed Since 2018 13,300 + fuses installed o r replaced Hazard Tree Management 2021 Completed/Target 131,400/120,000 trees assessed Completed Since 2018 359,000+ trees assessed Weather Stations 2021 Completed/Target 400/375 weather stations installed Completed Since 2018 1,460 + weather stations installed Aerial Fire Suppression Resources SCE contributed $18 million to support the creation of a quick reaction force of aerial firefighting assets across counties in SCE's service area to coordinate and reach wildfires in their early stages. These unique water and fire retardant dropping helitankers have the capability to operate day and night Critical Care Backup Battery 110 % completed 124 % completed 150 % completed 106 % completed 107 % completed 2021 Completed/Target 6,000/3,600 batteries provided to eligible customers Completed Since July 2020 6,740+ batteries provided to eligible customers 167 % completed 110 % completed

27 The 2021 fire season marks 3 consecutive years without a catastrophic wildfire associated with SCE’s infrastructure 1 February 25, 2022 SCE’s grid hardening and situational awareness measures ~30% of overhead wires in HFRA with covered conductor 2 1. While there is not universal consensus on the threshold that qualifies a wildfire as “catastrophic,” both OEIS and the SB 901 /AB 1054 statutory framework use the term to guide wildfire mitigation activities and regulatory requirements. For purposes of this presentation, SCE is using OEIS’s definition of a “catastrophic wil dfire,” which is as follows: A wildfire directly causing one or more deaths, damaging or destroying more than 500 structures, or burning more than 140,000 acres of land 2. HFRA = High Fire Risk Areas; refers to distribution infrastructure in HFRA 3. Based on 2021 weather and fuel conditions 4. CAL FIRE positions based on the 2017 - 18 California State Budget as originally enacted and the Governor’s Proposed 2022 - 23 Budget . Includes all CAL FIRE positions. Source of size of CAL FIRE fleet is CAL FIRE. Budget support for Wildfire & Forest Resilience Strategy includes $1.5 billion included in the 2021 - 22 state budget an d $1.2 billion included in the Governor’s Proposed 2022 - 23 Budget 80%+ of circuits 2 programmed with fast curve settings to protect against faults 1,460+ weather stations providing real - time weather data 166 HD cameras providing thorough coverage of HFRA California investment in wildfire suppression and prevention ~45% increase in CAL FIRE positions since 2017 4 SCE’s improved PSPS execution and community support 64 Community resource centers to provide resources and support for customers during PSPS events 6,000+ critical care backup batteries deployed in 2021 to support customers 60+ aircraft in CAL FIRE’s fleet — largest civil aerial firefighting fleet in the world 4 $2.7 billion State budget support for Wildfire & Forest Resilience Strategy 4 70%+ reduction in PSPS outage time in 2021 on frequently impacted circuits 3

28 SCE has made substantial progress on grid hardening and situational awareness measures February 25, 2022 Investments to harden the grid and enhance situational awareness targeted through 2023 Green shading represents completed measures through December 31, 2021, as proportionate to the 2023 forecast in SCE’s 2022 WMP Update filed on February 18, 2022 Covered Conductor ~5,330 circuit miles Fast - Acting Fuses ~14,270 Sectionalizing Devices 174 Wildfire Cameras 196 Weather Stations ~1,708 Targeted by 2023 Total Miles Covered To - Date 1 Tier 3 ~5,700 ~2,110 Tier 2 ~4,000 ~870 Total HFRA ~9,700 ~2,980 Overhead Distribution Lines in HFRA Circuit Miles SCE has focused on deploying covered conductor on the highest - risk circuits first to expeditiously reduce wildfire risk 86% 85% 82% 94% 56% 1. About 200 circuit miles of covered conductor of storm restoration work was distributed evenly between the tiers

29 SCE is making meaningful progress in mitigating wildfire risk for its customers February 25, 2022 Covered conductor has reduced faults, which could lead to ignitions High fire risk inspection program has reduced remediation needs Expanded vegetation management and tree removal has reduced faults 71% fewer faults on fully covered circuits 1 52% fewer tree - caused faults 2 66% lower defect find rate 3 1. Measured by faults covered conductor is expected to mitigate per 100 circuit miles on fully covered circuits as compared to b are circuits in 2021 in HFRA 2. Measured by average monthly tree caused circuit interruptions in HFRA in 2020 – 2021 as compared to the average from 2015 – 2019 3. Measured as Total Defect Find Rate (percentage of inspections) in 2021 as compared to 2019 (inception of program) for structu res inspected every year 4. Measured as structures damaged or destroyed in wildfires greater than 1,000 acres associated with SCE’s infrastructure during 20 15 – 2020, using red flag warning days as a proxy for PSPS conditions. Please note, however, that a red flag warning, alone, would not necessarily result in a decision to implement a PSPS On segments where SCE has covered bare wire, there has not been a CPUC - reportable ignition from the drivers that covered conductor is expected to mitigate Today’s PSPS use would have prevented majority of damage from past wildfires >90% reduction of structures damaged 4

30 SCE estimates its wildfire mitigation and PSPS have reduced probability of losses from catastrophic wildfires by ~65 - 70% 1,2 1. Baseline risk estimated by RMS using its wildfire model, the location of SCE’s assets, and SCE reported ignitions from 2014 - 2020 . Risk reduction calculated by applying SCE - provided mitigation effectiveness and locations of covered conductor, tree removals, inspections, line clearing, and PSPS. Ra nge may vary for other loss thresholds 2. Includes 50,000 year - long simulations using 20 years of weather and fire modeling weighted for the last 5 years to reflect recen t experience and climate - change impacts 3. Annual losses represent potential claims resulting from wildfire. Total potential insured losses, such as damages to assets o f h omeowners and businesses, estimated by RMS, and uninsured losses, such as personal injury, fire suppression, and damage to publicly - owned assets estimated by SCE based on m anagement experience and judgment 4. Fund refers to AB 1054 Wildfire Insurance Fund. SCE used the one - year RMS loss estimates with its estimates for the size of unin sured losses to quantify the reduction in probability of experiencing $3.5 billion in losses over a three - year period, excess of $1 billion aggregate each year, after whi ch the AB 1054 liability cap would apply SCE expects to further reduce risk and decrease the need for PSPS with continued grid hardening investments Pre - 2018 Q4 2021 Estimated Risk Reduction PSPS Contribution Annual Risk of ≥$1.0 billion loss 3 ~7.6% ~2.6% ~65% reduction in estimated probability of accessing the Wildfire Fund Risk of ≥$3.5 billion drawn from Fund over 3 years 3 ~4.2% ~1.3% ~70% reduction in estimated probability of exceeding AB 1054 liability cap 1. Baseline risk estimated by Risk Management Solutions, Inc. (RMS) using its wildfire model, relying on the following data prov ide d by SCE: the location of SCE’s assets, reported ignitions from 2014 – 2020, mitigation effectiveness and locations of installed covered conductor, tree removals, inspections, line clearing, and P SPS de - energization criteria 2. There are risks inherent in the simulation analyses, models and predictions of SCE and RMS relating to the likelihood of and dam age due to wildfires. As with any simulation analysis or model related to physical systems, particularly those with lower frequencies of occurrence and potentially high severity outcomes, the actu al losses from catastrophic wildfire events may differ from the results of the simulation analyses and models of RMS and SCE. Range may vary for other loss thresholds 3. Includes ( i ) total potential insured losses estimated by RMS, and (ii) total potential uninsured losses estimated by SCE based on manage men t experience and consultation with insurance industry experts. “Fund” refers to CA AB 1054 Wildfire Insurance Fund. SCE used RMS loss estimates along with its estimates of uninsur ed losses to quantify the reductions in estimated probability. Q4 2021 results now include a “Post Loss Amplification Factor” which accounts for dimensions like post - event resource scarcity (e.g., la bor, materials) February 25, 2022 30% of total risk reduction vs. 40% as of Q2 2021 Decreasing dependency on PSPS vs. 55% as of Q2 2021 vs. 65% as of Q2 2021

FINANCIAL INFORMATION

32 Range Case 2 n/a 6.0 5. 2 5.2 5.2 5.4 6.2 5.5 – 5.7 6.0 6.8 2021 2022 2023 2024 2025 SCE has significant capital expenditure opportunities driven by investments in the safety and reliability of the grid February 25, 2022 Capital deployment expected to increase beyond the current GRC cycle and will be proposed in future applications Capital Expenditures, $ in Billions Total 2021 – 2025 capital plan of $27 – 30 billion driven by investments in safety and reliability GRC track 1 and other approvals underpin spending through 2023 Primary 2023+ potential: – Deployment of incremental miles of covered conductor 3 – Investment to support infrastructure replacement and load growth – Transmission and energy storage investments to meet long - term state GHG targets 1. Forecast for 2024 includes amounts expected to be requested in track 4 of SCE’s 2021 GRC. Forecast for 2025 includes amounts cur rently expected to be requested in SCE’s 2025 GRC filing. Additionally, reflects non - GRC spending subject to future regulatory requests beyond GRC proceedings and FERC Formula Rate updat es 2. Annual Range Case capital reflects variability associated with future requests based on management judgment, potential for pe rmi tting delays and other operational considerations; GRC forecast is in line with authorized spend over the 2021 GRC track 1 cycle 3. The final decision in track 1 of SCE’s 2021 GRC established a cost recovery mechanism that would allow SCE to install additio nal covered conductor miles above the 4,500 circuit - mile level approved in the decision, including within the track 1 GRC period, subject to after - the - fact reasonableness review Future Requests 1

33 Range Case 2 n/a 38.5 41.2 43.8 46.6 2021 GRC track 1 decision provides rate base visibility through 2023; future applications expected to extend growth February 25, 2022 1. Weighted - average year basis. Excludes rate base associated with ~$1.6 billion of wildfire mitigation - related spend that shall no t earn an equity return under AB 1054 2. Range Case rate base reflects capital expenditure Range Case forecast 3. The final decision in track 1 of SCE’s 2021 GRC established a cost recovery mechanism that would allow SCE to install additio nal covered conductor miles above the 4,500 circuit - mile level approved in the decision, including within the track 1 GRC period, subject to after - the - fact reasonableness review From a 2021 base, rate base growth forecast of 7 – 9% through 2025, reflecting future incremental investment Rate Base 1 $ in Billions Forecast includes recovery of utility - owned storage for summer 2022 reliability and SCE’s building electrification request Substantial longer - term rate base growth potential from: – Deployment of incremental miles of covered conductor 3 – Investment to support infrastructure replacement and load growth – Transmission and energy storage investments to meet long - term state GHG targets 35.3 38.7 41.3 – 41.8 46.0 49.4 2021 2022 2023 2024 2025 ~9 % 2021 – 2025 CAGR Future Requests

34 SCE’s long - term growth drivers are highly aligned with California’s public policy goals Overarching Goals SCE Growth Drivers Safe, Reliable, and Affordable Electricity Service Infrastructure Replacement Sustained investment required to reach and maintain equilibrium replacement rate Wildfire Mitigation Significant investment in infrastructure and practices that mitigate wildfire risk, and bolster prevention and response Decarbonization of California Grid Modernization Accelerate the adoption and integration of renewables and other distributed energy resources Electrification of Transportation and Other Sectors Investments to support electrification of light - , medium - , and heavy - duty vehicles, buildings, and other sectors Energy Storage Energy storage essential to increasing carbon - free generation and reliability Transmission Future needs to meet renewables and clean energy mandates driven by CAISO planning process February 25, 2022

35 Cash flow from memo account recovery and securitization strengthens our balance sheet and credit metrics February 25, 2022 Approved Applications Application / Account Balance @ Dec. 31 Recovery Through Rate Recovery by Year 2022 2023 2024 2025 ✓ GRC Track 1 (Jan. – Sept. 2021 Balance) 642 Dec. ’23 321 321 – – ✓ GRC Track 2 401 Feb. ’25 111 134 134 22 ✓ 2020 – 2021 Residential Uncollectibles 1 193 Feb. ’25 129 34 26 4 ✓ WEMA1 189 Dec. ’22 189 – – – ✓ 2019 CEMA 62 Dec. ’22 62 – – – Total 1,487 812 489 160 26 Pending & Future Applications (Subject to CPUC Authorization) Application Request 2 Expected Amort. 2 Expected Rate Recovery by Year 3 2022 2023 2024 2025 GRC Track 3 497 12 months 290 207 – – WEMA2 215 12 months 125 90 – – 2022 CEMA (to be filed) 4 212 12 months – – 212 – 2021 CEMA 132 12 months – 77 55 – Total 1,056 415 374 267 – Expected Securitizations 5 AB 1054 Capital Included In: Amount 2022 2023 2024 2025 ✓ GRC Tracks 1 & 2 (completed) 518 518 – – – GRC Track 3 730 – 730 – – Total 1,248 518 730 – – 1. 2020 – 2021 Residential Uncollectibles are tracked in a balancing account authorized by the CPUC and implemented in rates without a separate application 2. Requested revenue requirement for GRC track 3, WEMA2, 2022 CEMA, and 2021 CEMA; and securitization of AB 1054 capex for GRC t rac ks 1 – 3. Amounts and amortization subject to CPUC approval 3. Actual timing will depend on the timing of CPUC authorizations and implementation in customer rates or execution of securitiz ati on transactions 4. In 2022, SCE expects to file CEMA requests for 2020 Emergency Wildfire Restoration for recovery of amounts incremental to aut hor ized revenue requirements. Final requested amount may change 5. Amounts reflect capital costs recovered upfront via securitization. Recovery in customer rates of costs to service the bonds tak es place over the tenor of the debt at a fixed recovery charge rate GRC, Uncollectibles, Wildfire - related, and Wildfire Insurance Applications $ in Millions

36 2017/2018 Wildfire/Mudslide Events Update: Less than 22% of best estimate remains February 25, 2022 SCE continues to make substantial progress resolving claims 1 Remaining expected potential losses, $ in Billions 7.5 1.6 Best Estimate of Total Losses Remaining Expected Potential Losses (At 12/31/2021) Less than 22 % of best estimate remains to be resolved SCE has not admitted wrongdoing or liability as part of any settlements California Attorney General's Office completed investigation of Thomas Fire and Woolsey Fire without pursuing criminal charges SCE will seek CPUC recovery of prudently - incurred, actual losses in excess of insurance 2 – SCE may seek recovery of 2017 and 2018 events in separate applications 1 1. After giving effect to approximately $131 million in fixed payments due under settlements executed before December 31, 2021, but not paid at December 31, 2021. In addition, the CPUC approved the SED Agreement in December 2021, but its approval has been legally challenged. SCE's obligations under the SED Agreement w ill only commence after CPUC approval of the SED Agreement is final and non - appealable 2. Other than for CPUC - jurisdictional rate recovery of the $375 million of losses foreclosed from cost recovery if the agreement wi th the Safety and Enforcement Division of the CPUC becomes final and non - appealable

37 CPUC’s scoping memo separates the 2022 cost of capital mechanism (CCM) into two steps 2022 cost of capital being addressed in ongoing proceeding; separately, IOUs will file cost of capital request for 2023 – ’25 February 25, 2022 Key Dates 2022 Cost of Capital Evidentiary hearing Feb. 24 – 25 Opening briefs Mar. 11 Reply briefs Mar. 25 Proposed decision on Phase 1 TBD Phase 2 (if necessary) TBD 2023 – 2025 Cost of Capital IOUs file applications April 20 1. In its application, and updated in its November 2021 compliance filing, SCE requested costs of capital of 10.53% for equity, 5.8 9% for preferred equity, and 4.32% for debt. As an alternative, SCE proposed maintaining its current ROE of 10.3% and setting the cost of preferred equity at 5.89% and the cost of debt at 4.32% Phase 1 (Current) Are there extraordinary circumstances that warrant a departure from the CCM for 2022?  ✓ or Cost of Capital Mechanism triggers; Phase 1 closes Equity 9.72% Preferred 5.89% Debt 4.32% WACC 7.21% Open Phase 2 to consider alternative proposals for 2022 1 Leave 2022 cost of capital at pre - 2022 levels; Phase 1 closes Equity 10.30% Preferred 5.70% Debt 4.74% WACC 7.68%

38 EIX has a strong track record of meeting or exceeding EPS guidance and growing its dividend 0.80 2.80 2004 2022 7.2% CAGR …and has 18 consecutive years of dividend growth 2 Dividends per Share (in Dollars) 1. EPS guidance was not provided in 2012 or 2018 because of the timing of final decisions in SCE’s 2012 and 2018 General Rate Ca ses , respectively 2. 2022 dividend annualized based on dividend declaration on December 9, 2021 EIX has consistently met or exceeded Core EPS guidance… Core EPS Relative to Guidance Range February 25, 2022 2004 Exceeded 2005 Exceeded 2006 Exceeded 2007 Exceeded 2008 In - line 2009 Exceeded 2010 In - line 2011 Exceeded 2012 N/A 1 2013 Exceeded 2014 Exceeded 2015 Exceeded 2016 In - line 2017 Exceeded 2018 N/A 1 2019 In - line 2020 In - line 2021 Exceeded

39 EIX and SCE are committed to maintaining their investment grade credit ratings SCE EIX Moody’s Baa2 Stable Baa3 Stable S&P BBB Stable BBB Stable Fitch BBB - Stable BBB - Stable Long - term Issuer Rating and Outlook As of February 24, 2022 Investment grade ratings at SCE and EIX, targeting EIX long - term FFO - to - Debt ratio of 15 – 17% Total liquidity of $4.4 billion 1 Debt maturities in 2022: – SCE: ~$365 million 2 – EIX: $700 million Credit strengths include 3 : – Stable, regulated T&D operations – Extensive cost recovery mechanisms – Credit supportive measures under AB 1054 – Wildfire mitigation investments 1. As of December 31, 2021, $1.6 billion at EIX and $2.8 billion at SCE includes amounts available under credit facilities and c ash on hand 2. Excludes amortization of securitized bonds related to SCE’s AB 1054 Excluded Capital Expenditures 3. As described by S&P in its reports dated September 10, 2021, and July 7, 2020, and Moody’s in its reports dated April 2, 2020 , a nd October 20, 2020 February 25, 2022

40 Edison Energy empowers organizations to conquer biggest challenges in energy today: Cost. Carbon. Complex Choices. Partners with market leaders to align energy spend with strategic, financial, and sustainability goals Provide independent, expert advice and services Using an integrated approach to design and implement strategic energy roadmaps for clients to achieve the right sustainability, performance, and cost outcomes for their organizations Deliver comprehensive data - driven portfolio solutions Provides suite of specialized services across sustainability, analytics, renewables, conventional supply, and energy optimization Serve large - scale, global customer base Clients include 22 of the Fortune 100 Offices in North America and Europe Helped customers execute 1.3+ GW of renewable energy agreements in 2021, bringing total offsite procurement to 8.0+ GW Provide insights for clean energy efforts Supports Edison International’s clean energy, electrification, and sustainability efforts February 25, 2022

41 EIX initiates 2022 core EPS guidance of $4.40 – 4.70 February 25, 2022 2022 Guidance 1 SCE 2022 Rate Base EPS 5.34 SCE Operational Variances 0.11 – 0.38 EIX Parent and Other (0.73) – (0.70 ) EIX Operational Results 4.72 – 5.02 SCE Costs Excluded from Authorized (0.32 ) EIX Consolidated Core EPS $4.40 – 4.70 1. 2022 guidance based on weighted average shares assumption of 381.4 million 2. SCE is unable to conclude, at this time, that these amounts are probable of recovery; however, recovery may be sought as part of future cost recovery applications Note: See Earnings Per Share Non - GAAP Reconciliations and Use of Non - GAAP Financial Measures in Appendix. All tax - effected infor mation on this slide is based on our current combined statutory tax rate of approximately 28%. Totals may not add due to rounding EIX 2022 Core Earnings Per Share Guidance Range Building from SCE Rate Base EPS Key components of variances from SCE rate base EPS 1 Rate Base EPS Recording at current cost of capital pending 2022 cost of capital decision SCE Operational Variances Includes financing benefits associated with 2022 cost of capital proceeding 0.10 EIX Parent and Other Operating expense, other (0.15) – (0.13 ) Interest expense (0.26 ) EIX preferred dividends (0.32) – (0.31 ) SCE Costs Excluded from Authorized Wildfire Insurance Fund contribution interest expense (0.09 ) Wildfire claims payment debt interest expense 2 (0.07 ) Short - and long - term incentive comp not in rates; SB 901 disallowed exec comp (0.16 )

42 2022 EIX Core Earnings Guidance Assumptions February 25, 2022 1. Beginning in 2023, Intervenors have an annual opportunity to terminate the TO2019A Formula Rate. The earliest any new rate co uld become effective is January 1, 2024 2. Does not include securities with equity content that could be issued to enable SCE to issue debt to finance payments for reso lut ion of claims related to the 2017/2018 Wildfire/Mudslide Events while allowing Edison International and SCE to maintain investment grade credit ratings Note: All tax - effected information on this slide is based on our current combined statutory tax rate of approximately 28% 2022 Assumption Additional Notes CPUC Rate Base ($ in Billions) $31.3 • Assumes CSRP track 1 decision in 2022. Decision delay would defer ~$55 million earnings to 2023 Return on Equity (ROE) 10.30% • ROE sensitivity: 4 cents EPS for 10bps change in ROE Equity in Capital Structure 52.0% FERC Rate Base ($ in Billions) $7.4 Return on Equity (ROE) 1 10.30% Equity in Capital Structure 1 47.5% Other Items SCE Operational Variances ($ Millions, after - tax) ~$40 – 145 Representative items: • AFUDC $120 • Financing benefits associated with 2022 cost of capital proceeding $38 • Shareholder - funded expenses not recovered in GRC $45 SCE Wildfire Claims Payment Debt Interest Expense ($ Millions, after - tax) ~$27 • SCE funds resolution of wildfire claims with debt. Additional debt expected to be issued during 2022 • $3 billion outstanding at 12/31/2021 EIX Equity Issuance 2 ($ in Millions) ~$300 – 400 of equity content • Higher than average of up to $250/year in 2022 – ’25 driven by anticipated capex associated with SCE's utility owned storage projects EIX Preferred Dividends ($ in Millions) ~$120

43 EIX parent projects total 2022 financing needs of $1.2 billion, including $300 – 400 million equity content February 25, 2022 1. Financing plans are subject to change 2. Edison International expects to issue securities containing up to $250 million of equity content annually, on average from 20 22 through 2025. The higher - than - average equity content expected in 2022 is driven by the anticipated capital expenditures associated with SCE's utility owned storage projects $1,200 $700 parent debt maturities $500 investment in SCE to support rate base growth Use of Proceeds 2022 EIX Financing Plan 1 $ in Millions Expect to issue securities with $300 – 400 million of equity content (consistent with prior disclosure) 2 in combination of: – Potential for cash proceeds of ~$400 – 600 million from preferred equity issuance (50% equity content) – ~$100 million common equity via internal programs (100% equity content) – If needed, use of at - the - market program (100% equity content) Expect to refinance $700 million of parent debt maturities with new debt issuances

44 4.52 4.40 – 4.70 5.50 – 5.90 2021 Guidance Midpoint 2022 Guidance 2023 2024 2025 EIX reaffirms 2021 – 2025 EPS growth rate target, which would result in 2025 EPS of $5.50 – 5.90 February 25, 2022 Earnings progression expected to continue to 2025 Core Earnings per Share 1. Based on the midpoint of initial 2021 Core EPS guidance range of $4.42 – 4.62 established September 16, 2021 2. Components are rounded to the nearest 5 cents and based on EIX 2022 guidance share count of 381.4 million shares. For the pur pos es of this illustration, all costs and dilution associated with any equity content issued beyond 2022 are reflected in the EIX Parent and Other line. Actual financing activity may vary and is s ubj ect to change 5 – 7% 2021 – ’25 CAGR 1 • Annual core EPS growth during the period expected to be non - linear • Growth in any given year can be outside the range 1 2025 Core EPS Components 2 Core Earnings per Share Key Assumptions • 2025 rate base ($bn) $46.6 – 49.4 – FERC ~16% of rate base • Authorized ROE 10.30% • Not assuming financing benefits during 2023 – 2025 period • Up to $250 million per year, on average, equity content 2022 – 2025, as previously disclosed Approximate Ranges 2 2025 Rate Base EPS $6.45 – 6.90 SCE Op. Variances 0.20 – 0.30 EIX Parent and Other (including dilution) (0.80) – (0.95 ) SCE Costs Excluded from Authorized (0.35 ) EIX Cons. Core EPS $5.50 – 5.90

45 EIX has double - digit total return potential, supported by leadership role in clean energy transition February 25, 2022 9 – 11%+ total return o pportunity 4 before potential P/E multiple expansion driven by estimated 65 – 70% risk reduction to - date, a nd ongoing utility and government wildfire mitigation efforts 1. Compound annual growth rate (CAGR) based on the midpoint of the 2021 Core EPS guidance range of $4.42 – 4.62 established on Septem ber 16, 2021 2. Based on EIX stock price on February 23, 2022 3. Building electrification programs subject to CPUC approval 4. At current P/E multiple. Excludes changes in P/E multiple and potential dividend growth 5 – 7% core EPS CAGR 1 2021 to 2025 Strong rate base growth of ~7 – 9% $27 – 30 billion 2021 – 2025 capital program 4%+ current dividend yield 2 Target dividend payout of 45 – 55% of SCE core earnings Investments in safety and reliability of the grid Wildfire mitigation execution reduces risk for customers Creates strong foundation for climate adaptation and the clean energy transition One of the strongest electrification profiles in the industry Industry - leading programs for transportation electrification and building electrification 3 Potential for 60% load growth by 2045

APPENDIX

47 SCE Key Regulatory Proceedings Proceeding Description and Next Steps Base Rates 2021 GRC Track 4 (A.19 - 08 - 013) Set CPUC base revenue requirement for third attrition year (2024) Track 4 to be filed Q2 2022 2022 Cost of Capital (A.21 - 08 - 013) Establish cost of capital for 2022 Opening briefs and reply briefs for first phase to be served in March 2022. Timing of proposed decision to be determined CSRP Track 1 (A.21 - 07 - 009) Requesting approval of $483MM of capital and $40MM of O&M recorded in CSRP memorandum account through April 2021 Intervenor testimony to be served in March 2022. Proposed decision scheduled for Q3 - Q4 2022 Wildfire 2021 GRC Track 3 (A.19 - 08 - 013) Incremental 2020 wildfire mitigation costs and GS&RP costs above settled amounts . Reasonableness review: $679MM capital, $476MM O&M; Rev. Req.: $497MM 1 Proposed decision expected Q1 2022 Insurance WEMA2 (A.20 - 12 - 010) Approx. $215MM for wildfire insurance - related costs for July – Dec. 2020 Proposed decision pending 2022 WMP Update Update to 2020 – 2022 WMP outlining continued efforts Stakeholders submit comments due in March February 25, 2022 1. Capital reflects direct costs. Revenue requirement does not include revenue associated with AB 1054 Excluded Capital Expendit ure s

48 Low High Basic EIX EPS $4.40 $4.70 Total Non - Core Items 2 — — Core EIX EPS $4.40 $4.70 1. EPS is calculated on the assumed weighted - average share count for 2022 of 381.4 million 2. Non - core items are presented as they are recorded Earnings Per Share Non - GAAP Reconciliations February 25, 2022 Reconciliation of EIX Basic Earnings Per Share Guidance to EIX Core Earnings Per Share Guidance 1 2022 EPS Attributable to Edison International

49 Edison International's earnings are prepared in accordance with generally accepted accounting principles used in the United States. Management uses core earnings (losses) internally for financial planning and for analysis of performance. Core earnings (losses) 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 (losses) are a non - GAAP financial measure and may not be comparable to those of other companies. Core earnings (losses) are defined as earnings attributable to Edison International shareholders less non - core items. Non - core items include 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 write downs, asset impairments and other income and expense related to changes in law, outcomes in tax, regulatory or legal proceedings, and exit activities, including sale of certain assets and other activities that are no longer continuing. 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 Derek Matsushima, Senior Manager (626) 302 - 2540 (626) 302 - 3625 Sam.Ramraj@edisonintl.com Derek.Matsushima@edisonintl.com Use of Non - GAAP Financial Measures February 25, 2022