Edison International (EIX)

Company ID: 184 | CIK: 0000827052
10-Q view:
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-Q YTD data
No 10-Q 3M data
No 10-K data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-K data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
No 10-Q 3M data
Segments are charted by their disclosed metrics (revenue, segment profit, etc.). Each line is a single segment. Reconciliation/corporate items are excluded. Major customers are shown as a percentage of revenue. Operational KPIs are grouped by metric concept; sub-metrics appear as separate lines.

Geographic Segments

Business Unit / Product Segments

Major Customers (% of Revenue)

Operational KPIs

PBOP Plan Assets (aum)

Power purchase agreement commitments (backlog)

No 10-Q data

Turbine purchase commitments (bookings)

No 10-K data

Renewable development pipeline (capacity)

Employee Turnover Rate (churn)

No 10-Q data

Wildfire-related claims accrued (claims_count)

No 10-K data

Contractors (contractors)

No 10-Q data

Customers (customers)

Service territory population (customers_served)

Forced Outage Rate (defect_rate)

No 10-Q data

GHG emissions (emissions_co2)

No 10-Q data

Leased coal railcars (fleet_size)

No 10-Q data

Generation capacity (generation_capacity)

Kilowatt-hour deliveries (generation_volume)

Full-time employees (headcount)

Wind turbines in storage (inventory_units)

Load factor (load_factor)

No 10-K data

Market Value of Voting Stock (market_cap)

No 10-Q data

Wind turbine commitments (orders_received)

2017/2018 insurance recoveries (other)

No 10-K data

2017/2018 remaining loss estimate (other)

No 10-K data

2017/2018 settlement payments (other)

No 10-K data

2017/2018 wildfire losses accrued (other)

No 10-K data

2017/2018 wildfire settlements paid (other)

No 10-K data

2017/2018 wildfire total pre-tax charges (other)

No 10-K data

2025 GRC revenue requirement (other)

No 10-K data

AB 1054 Excluded Capital Expenditures (other)

AB 1054 capex invested (other)

No 10-K data

AB 1054 excluded capex (other)

No 10-K data

AB 1054 excluded capital expenditures (other)

No 10-K data

AB 1054 liability cap (other)

No 10-K data

AFUDC debt (other)

No 10-Q data

AFUDC equity (other)

No 10-Q data

ARO Liability (other)

No 10-Q data

ARO liability (other)

No 10-Q data

Above-market qualifying facility power purchases (other)

No 10-K data

Accounting change benefit (other)

No 10-K data

Accrued Wildfire Liability (other)

No 10-K data

Accrued Wildfire Losses (other)

No 10-K data

Accrued capital expenditures (other)

Accrued interest and penalties (other)

No 10-Q data

Accrued severance liability (other)

No 10-Q data

Accrued wildfire claims (other)

No 10-K data

Accrued wildfire liabilities (other)

No 10-K data

Accrued wildfire liability (other)

No 10-K data

Accrued wildfire losses (other)

No 10-K data

Accumulated deferred income tax liability (other)

No 10-Q data

Accumulated other comprehensive loss (other)

No 10-K data

Acres burned (other)

No 10-K data

Additional mortgage bond issuance capacity (other)

No 10-K data

Additional remediation exposure (other)

No 10-K data

Additional wildfire insurance coverage (other)

No 10-K data

Advanced meters to be deployed (other)

No 10-K data

Affordable Housing Units (other)

No 10-Q data

Affordable housing net investment (other)

No 10-Q data

Affordable housing projects (other)

No 10-Q data

Affordable housing units (other)

No 10-Q data

Aggregate Market Value of Voting Stock (other)

No 10-Q data

Aggregate contracted capacity from VIEs (other)

No 10-K data

Aggregate market value of voting stock (other)

No 10-Q data

Allowance for uncollectible accounts (other)

Annual common stock dividend (other)

No 10-K data

Annual customer rate reduction (other)

No 10-K data

Annual dividend rate (other)

No 10-Q data

Annual nuclear decommissioning contribution (other)

No 10-K data

Annual remediation costs range high (other)

No 10-K data

Annual remediation costs range low (other)

No 10-K data

Area and street lights (other)

No 10-Q data

Area and streetlights (other)

No 10-Q data

Asbestos cases pending (other)

No 10-K data

Asset Retirement Obligation (other)

Asset retirement obligation (other)

Asset retirement obligations (other)

Authorized CPUC rate base (other)

No 10-Q data

Authorized GRC revenue requirement (other)

No 10-Q data

Authorized ROE (other)

Authorized Return on Equity (other)

No 10-K data

Authorized capital expenditures (other)

No 10-K data

Authorized capital structure (other)

No 10-Q data

Authorized common equity ratio (other)

No 10-K data

Authorized rate change (other)

No 10-K data

Authorized rate of return on common equity (other)

No 10-Q data

Authorized return on common equity (other)

Authorized return on equity (other)

Authorized return on rate base (other)

No 10-K data

Authorized revenue requirement (other)

Available Credit Facility (other)

No 10-Q data

Available Liquidity (other)

No 10-K data

Available borrowing capacity (other)

No 10-K data

Available credit capacity (other)

No 10-K data

Available credit facility (other)

No 10-K data

Available credit facility capacity (other)

No 10-K data

Available liquidity (other)

Average Market Price (other)

No 10-K data

Average PJM power price (other)

No 10-K data

Average SO2 Allowance Price (other)

No 10-K data

Average electricity price (other)

No 10-K data

Average energy market price (other)

No 10-K data

Average energy price (other)

No 10-K data

Average fuel cost (other)

No 10-Q data

Average fuel costs (other)

No 10-K data

Average hedge price (other)

No 10-K data

Average power purchase price (other)

No 10-K data

Average rate per kWh (other)

No 10-K data

Average realized energy price (other)

No 10-K data

Average realized fuel cost (other)

No 10-K data

Average retail electricity rate (other)

No 10-K data

Average retail rate (other)

No 10-Q data

Average system rate (other)

No 10-Q data

BP revenue concentration (other)

No 10-K data

BRRBA undercollections increase (other)

No 10-K data

Baa utility bond yield (other)

No 10-K data

Balancing account over-collections (other)

No 10-Q data

Base rate revenue account overcollection (other)

No 10-Q data

Basic earnings per share (other)

No 10-Q data

Book balances reclassified to accounts payable (other)

No 10-K data

Borrowing Capacity Available (other)

No 10-K data

Borrowing capacity available (other)

No 10-K data

Brooklyn Navy Yard funding (other)

No 10-K data

Brooklyn Navy Yard spent (other)

No 10-K data

Bundled service system average rate (other)

No 10-K data

Busbar price basis discount (other)

No 10-K data

CCA Load Share (other)

No 10-Q data

CCA load share (other)

No 10-Q data

CCA service load share (other)

No 10-Q data

CCAs in territory (other)

No 10-Q data

COVID-19 Net Costs (other)

No 10-K data

COVID-19 incremental costs (other)

No 10-K data

COVID-19 incremental uncollectible costs (other)

No 10-K data

COVID-19 memorandum accounts (other)

No 10-K data

COVID-19 net costs (other)

No 10-K data

CPUC distribution return on equity (other)

No 10-K data

CPUC ex parte penalty (other)

No 10-Q data

CPUC rate base (other)

No 10-Q data

CRR hedge notional (other)

No 10-K data

CRR notional (other)

No 10-K data

CRR notional volume (other)

No 10-K data

Canadian gas disallowance recommendation (other)

No 10-K data

Canadian gas supply contracts (other)

No 10-Q data

Capacity price (other)

No 10-K data

Capital Expenditures (other)

Capital Expenditures Forecast (other)

No 10-K data

Capital expenditure forecast (other)

No 10-K data

Capital expenditures (other)

Capital expenditures forecast (other)

No 10-K data

Capital expenditures forecast 2015 (other)

No 10-K data

Capital expenditures forecast range (other)

No 10-K data

Capital expenditures forecast reduction (other)

No 10-K data

Capital structure (other)

No 10-Q data

Capitalized software amortization expense (other)

No 10-Q data

Capitalized software costs (other)

No 10-Q data

Carbon-free energy percentage (other)

No 10-Q data

Cash and equivalents (other)

No 10-K data

Cash collateral posted (other)

No 10-K data

Cash flow coverage of dividends (other)

No 10-K data

Cash on Hand (other)

No 10-K data

Cash on hand (other)

No 10-K data

Cash payments for interest (other)

No 10-K data

Cash payments for taxes (other)

No 10-K data

Cash reserves (other)

No 10-K data

Charge Ready 2 ports proposed (other)

No 10-K data

Charge Ready Sites (other)

No 10-Q data

Charge Ready Transport vehicles (other)

No 10-Q data

Charge Ready charge ports (other)

Charge Ready charging stations (other)

No 10-Q data

Charge Ready pilot program (other)

No 10-Q data

Charge Ready ports (other)

No 10-Q data

Charge Ready ports deployed (other)

No 10-K data

Charge Ready sites (other)

No 10-Q data

Charge Ready vehicles (other)

No 10-Q data

Charge ports (other)

No 10-Q data

Charge ports completed (other)

No 10-Q data

Charge ports installed (other)

No 10-Q data

Charge ports supported (other)

No 10-Q data

Cities and communities served (other)

No 10-Q data

Cities served (other)

No 10-Q data

Civic, political and related activities and donations (other)

No 10-K data

Coal Requirements Under Contract (other)

No 10-K data

Coal contract coverage (other)

No 10-K data

Coal market price (other)

No 10-K data

Coal price (other)

No 10-K data

Coal requirements under contract (other)

Coal shipments received (other)

No 10-K data

Coal under contract (other)

Collateral Posted (other)

No 10-K data

Collateral not offset against derivative liabilities (other)

No 10-K data

Collateral posted (other)

Collateral requirements (other)

Collateralized mortgage obligations in nuclear decommissioning trusts (other)

No 10-K data

Commercial Paper Outstanding (other)

No 10-K data

Commercial paper outstanding (other)

Common Equity Component (other)

No 10-K data

Common Shares Outstanding (other)

Common Stock Outstanding (other)

Common Stock Shares Outstanding (other)

No 10-Q data

Common Stock outstanding (other)

No 10-K data

Common Stock shareholders (other)

No 10-Q data

Common Stock shareholders of record (other)

No 10-Q data

Common equity component (other)

No 10-K data

Common equity component of capitalization (other)

No 10-K data

Common equity component of total capitalization (other)

No 10-K data

Common equity ratio (other)

No 10-K data

Common equity to total capitalization (other)

No 10-K data

Common equity to total capitalization ratio (other)

No 10-K data

Common shareholders equity (other)

No 10-Q data

Common shares outstanding (other)

Common shares repurchased (other)

No 10-K data

Common stock closing price (other)

No 10-Q data

Common stock outstanding (other)

Common stock price range (other)

No 10-Q data

Common stock repurchase authorization (other)

No 10-K data

Common stock repurchase value (other)

No 10-K data

Common stock repurchased (other)

No 10-K data

Common stock shareholders of record (other)

No 10-Q data

Common stock shares outstanding (other)

No 10-Q data

Common stockholders of record (other)

No 10-Q data

Communities served (other)

No 10-Q data

Community choice aggregations (other)

No 10-Q data

Competition transition charge estimate (other)

No 10-K data

Congestion revenue rights notional (other)

No 10-K data

Congestion revenue rights notional volume (other)

Consolidated wind projects (other)

No 10-K data

Construction expenditures (other)

No 10-K data

Construction work in progress (other)

No 10-Q data

Contracted VIE capacity (other)

No 10-Q data

Contractor DART rate (other)

No 10-Q data

Coolwater-Lugo project capital expenditures (other)

No 10-K data

Coolwater-Lugo project capital expenditures 2015-2017 (other)

No 10-K data

Core earnings (other)

Corporate bonds in nuclear decommissioning trusts (other)

No 10-K data

Corporate cash (other)

No 10-K data

Corporate debt to corporate capital (other)

No 10-K data

Corporate expenses and other (other)

No 10-Q data

Coso parties cross-complaint damages (other)

No 10-K data

Coso parties cross-complaint punitive damages (other)

No 10-K data

Costs of removal regulatory liability (other)

Counterparty credit exposure (other)

No 10-K data

Counterparty credit risk exposure (other)

No 10-K data

Covered conductor miles authorized (other)

No 10-K data

Covered conductor miles installed (other)

No 10-K data

Credit Facility Availability (other)

No 10-K data

Credit Facility Capacity (other)

No 10-Q data

Credit Risk Exposure (other)

No 10-K data

Credit facility availability (other)

Credit risk exposure (other)

Credit-risk contingent collateral (other)

No 10-Q data

Critical systems Year 2000 ready (other)

No 10-K data

Cumulative common stock repurchased (other)

No 10-K data

Cumulative common stock repurchased value (other)

No 10-K data

Cumulative wildfire losses (other)

No 10-K data

Current transmission return on assets (other)

No 10-K data

Customer class revenue mix (other)

No 10-Q data

Customer minutes interrupted (other)

No 10-Q data

Customer refund from GRC (other)

No 10-Q data

Customer refund liability (other)

No 10-K data

Customers impacted by PSPS (other)

No 10-Q data

DART rate (other)

No 10-Q data

DOE damages sought (other)

No 10-K data

DOE fee paid (other)

No 10-K data

DOE quarterly fee (other)

No 10-K data

DOE spent fuel damages claim (other)

No 10-Q data

Debt service coverage ratio (other)

No 10-K data

Debt to Total Capitalization (other)

No 10-K data

Debt to Total Capitalization Ratio (other)

No 10-K data

Debt to capital ratio (other)

No 10-K data

Debt to capitalization (other)

No 10-K data

Debt to capitalization ratio (other)

No 10-K data

Debt to total capitalization (other)

Debt to total capitalization ratio (other)

Debt-to-capital ratio (other)

No 10-K data

Decommissioning cost estimate (other)

Decommissioning cost present value (other)

Decommissioning costs (other)

No 10-K data

Decommissioning trust assets (other)

No 10-K data

Decommissioning trust contributions (other)

No 10-K data

Deferred financing costs (other)

No 10-Q data

Deferred income taxes and credits (other)

No 10-Q data

Deferred income taxes net (other)

No 10-K data

Deferred income taxes regulatory asset (other)

No 10-Q data

Demands received (other)

No 10-K data

Depreciation expense (other)

No 10-Q data

Depreciation rate (other)

No 10-Q data

Derivative Net Asset (other)

No 10-K data

Derivative Net Liability (other)

No 10-K data

Derivative instruments fair value (other)

No 10-K data

Derivative liabilities (other)

No 10-Q data

Derivative net liability (other)

Derivative notional volume (other)

No 10-K data

Derivative notional volumes (other)

No 10-K data

Diluted earnings per share (other)

No 10-Q data

Direct access and CCA load share (other)

No 10-Q data

Direct access customers (other)

No 10-Q data

Director Annual Reelection Award (other)

No 10-K data

Director Initial Election Award (other)

No 10-K data

Director annual Audit Committee Chair retainer (other)

No 10-K data

Director annual Board Committee Chair retainer (other)

No 10-K data

Director annual Compensation and Executive Personnel Committee Chair retainer (other)

No 10-K data

Director annual Lead Director retainer (other)

No 10-K data

Director annual board retainer (other)

No 10-K data

Director quarterly board retainer installment (other)

No 10-K data

Directors elected (other)

No 10-K data

Disconnection rate cap (other)

No 10-K data

Distribution Capex (other)

No 10-Q data

Distribution Lines (other)

No 10-Q data

Distribution PBR return on equity (other)

No 10-K data

Distribution authorized return (other)

No 10-K data

Distribution circuit miles (other)

No 10-Q data

Distribution circuit-miles (other)

No 10-Q data

Distribution line miles (other)

No 10-Q data

Distribution lines (other)

No 10-Q data

Distribution overhead lines (other)

No 10-Q data

Distribution overhead miles (other)

No 10-Q data

Distribution poles (other)

No 10-Q data

Distribution return (other)

No 10-K data

Distribution return on investment (other)

No 10-K data

Distribution substations (other)

No 10-Q data

Distribution transformers (other)

No 10-Q data

Distribution underground lines (other)

No 10-Q data

Distribution underground miles (other)

No 10-Q data

Distributions from subsidiaries (other)

No 10-K data

Distributions received (other)

No 10-K data

Distributions received by EME (other)

No 10-K data

Dividend Payout Ratio (other)

No 10-Q data

Dividend coverage ratio (other)

No 10-K data

Dividend distributions from trusts (other)

No 10-K data

Dividend income from trusts (other)

No 10-K data

Dividend increase (other)

No 10-K data

Dividend paying capacity (other)

No 10-K data

Dividend payout ratio (other)

No 10-K data

Dividends declared but not paid (other)

No 10-K data

Dividends declared per common share (other)

No 10-K data

Dividends declared per share (other)

Dividends paid to Edison International (other)

No 10-K data

EEI SIF rate (other)

No 10-Q data

EIX debt-to-capital ratio (other)

No 10-K data

EIX shares outstanding (other)

No 10-K data

EME Interest Coverage Ratio (other)

No 10-K data

EME Settlement initial cash payment (other)

No 10-K data

EME Settlement payment due (other)

No 10-K data

EME contingent obligations (other)

No 10-K data

EME corporate cash (other)

No 10-K data

EME credit facility availability (other)

No 10-K data

EME firm commitments (other)

No 10-K data

EME interest coverage ratio (other)

No 10-K data

EME operating facilities (other)

No 10-Q data

EME operating projects (other)

No 10-Q data

EME settlement payment (other)

No 10-Q data

ERRA Undercollection (other)

No 10-K data

ERRA and PABA undercollections (other)

No 10-Q data

ERRA balance (other)

No 10-K data

ERRA balancing account (other)

ERRA balancing account overcollection (other)

No 10-K data

ERRA balancing account undercollection (other)

ERRA overcollection (other)

ERRA under-collection (other)

No 10-K data

ERRA undercollection (other)

ERRA undercollection balance (other)

No 10-K data

ERRA undercollections decrease (other)

No 10-K data

EV charge ports (other)

No 10-Q data

Earnings per share (other)

No 10-K data

Eaton Fire Acres Burned (other)

No 10-K data

Eaton Fire Structures Damaged (other)

No 10-K data

Eaton Fire Structures Destroyed (other)

No 10-K data

Eaton Fire Suppression Costs (other)

No 10-K data

Eaton Fire acres burned (other)

No 10-K data

Eaton Fire area burned (other)

No 10-K data

Eaton Fire civilian fatalities (other)

No 10-K data

Eaton Fire individual plaintiffs (other)

No 10-K data

Eaton Fire lawsuits (other)

No 10-K data

Eaton Fire plaintiffs (other)

No 10-K data

Eaton Fire structures destroyed (other)

No 10-K data

Eaton Fire suppression costs (other)

No 10-K data

Edison Capital affordable housing sale (other)

No 10-Q data

Edison Capital earnings (other)

No 10-Q data

Edison Capital firm commitments (other)

No 10-K data

Edison Energy Group capital expenditures (other)

No 10-Q data

Edison Energy Group loss (other)

No 10-Q data

Edison Energy acquisitions (other)

No 10-Q data

Edison International debt to capitalization (other)

No 10-K data

Edison International debt to total capitalization (other)

No 10-K data

Edison Mission Group income (other)

No 10-Q data

Effective Tax Rate (other)

No 10-K data

Effective tax rate (other)

Electrical load change (other)

No 10-K data

Electricity derivative notional (other)

No 10-K data

Electricity derivative notional volume (other)

No 10-Q data

Electricity hedge notional (other)

No 10-K data

Electricity hedge notional volume (other)

No 10-K data

Electricity notional volume (other)

No 10-K data

Electricity sales (other)

No 10-Q data

Electricity sales volume growth (other)

No 10-K data

Emission allowance price (other)

No 10-K data

Emission allowance purchase price (other)

No 10-K data

Employee DART rate (other)

No 10-Q data

Employee EEI SIF rate (other)

No 10-Q data

Employee Training Completion (other)

No 10-Q data

Employee Turnover Rate (other)

No 10-Q data

Employee turnover rate (other)

No 10-Q data

Energy derivatives regulatory asset (other)

No 10-K data

Energy efficiency incentive awards (other)

No 10-Q data

Energy efficiency incentives requested (other)

No 10-K data

Energy price (other)

No 10-K data

Energy resource recovery account balance (other)

No 10-K data

Energy source mix (other)

No 10-Q data

Energy sources (other)

No 10-Q data

Energy sources mix (other)

No 10-Q data

Energy storage procurement target (other)

No 10-Q data

Energy supply mix (other)

No 10-Q data

Environmental Liability (other)

Environmental Remediation Liability (other)

No 10-K data

Environmental capital expenditures (other)

No 10-K data

Environmental cleanup cost range upper (other)

No 10-K data

Environmental cleanup costs incurred (other)

No 10-K data

Environmental cleanup liability (other)

No 10-K data

Environmental cleanup period (other)

No 10-K data

Environmental cleanup potential excess (other)

No 10-K data

Environmental cleanup recovery (other)

No 10-K data

Environmental cleanup shareholder funding (other)

No 10-K data

Environmental cleanup sites (other)

Environmental liability (other)

No 10-K data

Environmental liability potential excess (other)

No 10-K data

Environmental liability recorded (other)

No 10-K data

Environmental liability upper limit (other)

No 10-K data

Environmental regulatory asset (other)

No 10-K data

Environmental remediation annual costs (other)

No 10-Q data

Environmental remediation cost range (other)

No 10-Q data

Environmental remediation costs (other)

No 10-K data

Environmental remediation costs recorded (other)

No 10-K data

Environmental remediation liability (other)

Environmental remediation regulatory asset (other)

No 10-Q data

Environmental remediation sites (other)

Environmental sites identified (other)

No 10-K data

Environmental sites with CPUC recovery (other)

No 10-K data

Equity allowance for funds used during construction (other)

No 10-K data

Equity investments in United States (other)

No 10-K data

Equivalent availability (other)

Estimated Losses for 2017/2018 Wildfires (other)

No 10-K data

Estimated Nuclear Decommissioning Cost (other)

No 10-Q data

Estimated nuclear decommissioning cost (other)

No 10-Q data

Estimated remaining wildfire losses (other)

No 10-K data

Estimated wildfire liabilities (other)

No 10-K data

Excess cost of mandated power purchases (other)

No 10-K data

Exelon revenue concentration (other)

No 10-K data

Exelon share of Illinois sales (other)

No 10-K data

Expected FERC Rate Recovery (other)

No 10-K data

Expected Insurance Recovery (other)

No 10-K data

Expected insurance recoveries (other)

No 10-K data

Expected return on pension plan assets (other)

No 10-Q data

FERC authorized ROE (other)

No 10-Q data

FERC proposed return on equity (other)

No 10-K data

FERC rate recoveries (other)

No 10-Q data

FERC transmission rate case revenue requirement (other)

No 10-K data

FERC transmission return on assets (other)

No 10-K data

FERC transmission revenue increase (other)

No 10-Q data

FERC transmission revenue requirement (other)

No 10-K data

FERC wildfire recoveries (other)

No 10-K data

FERC wildfire recoveries remaining (other)

No 10-K data

Fair value of derivative instruments (other)

No 10-K data

Female workforce share (other)

No 10-Q data

Fin Toll hedge notional (other)

No 10-K data

Fin Toll notional volume (other)

No 10-K data

Financial transmission rights purchased (other)

No 10-K data

Firm equity commitments (other)

No 10-K data

First and refunding mortgage bonds issued (other)

No 10-K data

Forced outage rate (other)

Forecasted capital expenditures (other)

No 10-Q data

Forecasted rate base (other)

Forward PJM power price (other)

No 10-K data

Forward energy price (other)

No 10-K data

Forward power price (other)

No 10-K data

Forward-looking return on rate base (other)

No 10-K data

Fossil and hydro authorized return (other)

No 10-K data

Fossil and hydro generation authorized return (other)

No 10-K data

Fossil and hydro return (other)

No 10-K data

Fossil and hydroelectric return on equity (other)

No 10-K data

Franchise fees billed (other)

No 10-Q data

Fuel costs (other)

No 10-K data

GHG allowances held (other)

No 10-Q data

GHG emission obligations (other)

No 10-Q data

GRC post-test year increase 2016 (other)

No 10-K data

GRC post-test year increase 2017 (other)

No 10-K data

GRC revenue refund (other)

No 10-K data

GRC revenue requirement decrease (other)

No 10-K data

GRC revenue requirement request (other)

No 10-K data

GS&RP Capital Expenditures (other)

No 10-K data

GS&RP O&M Expenses (other)

No 10-K data

GS&RP capital expenditures (other)

No 10-K data

GS&RP operating expenses (other)

No 10-K data

Generating plants (other)

No 10-Q data

Generation Capex (other)

No 10-Q data

Generation load factor (other)

No 10-Q data

Generation plants approved for divestiture (other)

No 10-K data

Generation plants divested (other)

No 10-K data

Generation-related regulatory asset at risk (other)

No 10-K data

Generation-related regulatory assets (other)

No 10-K data

Goodwill (other)

No 10-K data

Gross derivative assets (other)

No 10-K data

Gross derivative liabilities (other)

No 10-K data

HLBV income allocated to tax equity investors (other)

No 10-K data

HLBV income allocation (other)

No 10-Q data

Health care cost trend rate (other)

No 10-Q data

Hedge position (other)

No 10-Q data

Hedge price (other)

No 10-K data

Hedged average price (other)

No 10-K data

Hedged electricity volume (other)

No 10-K data

Hedged energy price (other)

No 10-K data

Hedged energy volume (other)

Hedged generation volume (other)

No 10-K data

Hedged power sales (other)

No 10-Q data

Hedged power volume (other)

No 10-K data

Hedging notional volume (other)

No 10-Q data

High Fire Risk Area (other)

No 10-Q data

High Fire Risk Territory (other)

No 10-K data

High fire risk area (other)

High fire risk area share (other)

No 10-K data

High fire risk service area (other)

No 10-Q data

High fire risk service territory (other)

No 10-Q data

High fire risk share (other)

No 10-Q data

High fire risk territory (other)

High fire risk territory share (other)

Housing units (other)

No 10-Q data

Hydroelectric asset market value filing (other)

No 10-K data

Hydroelectric plants (other)

No 10-Q data

Hydroelectric revenue sharing recovery (other)

No 10-K data

Hydroelectric revenue sharing refund (other)

No 10-K data

ISFSI costs (other)

No 10-K data

ISO ancillary services price cap (other)

No 10-K data

ISO imbalance energy price cap (other)

No 10-K data

ISO price cap (other)

No 10-K data

Identified environmental remediation sites (other)

No 10-K data

Identified environmental sites (other)

Identified material environmental sites (other)

No 10-K data

Identified remediation sites (other)

No 10-K data

Immaterial remediation sites (other)

No 10-K data

Income from discontinued operations (other)

No 10-K data

Income tax benefits from uncertain tax positions (other)

No 10-K data

Increase in cash surrender value of life insurance policies (other)

No 10-K data

Incremental inspection and repair costs (other)

No 10-K data

Incremental wildfire expenses subject to review (other)

No 10-K data

Incremental wildfire mitigation regulatory assets (other)

No 10-K data

Individual plaintiffs (other)

No 10-K data

Individual plaintiffs outstanding (other)

No 10-K data

Individual plaintiffs settled (other)

No 10-K data

Infrastructure fund investments (other)

No 10-Q data

Inspection and repair costs (other)

No 10-K data

Insurance claim filed (other)

No 10-K data

Insurance recoveries (other)

No 10-K data

Insurance recoveries receivable (other)

No 10-K data

Insurance recoveries received (other)

No 10-Q data

Interest Coverage Ratio (other)

No 10-K data

Interest coverage ratio (other)

No 10-K data

Interest income (other)

No 10-K data

Investment grade counterparty share (other)

No 10-K data

Italian wind project equity contribution obligations (other)

No 10-K data

Italian wind project purchase price (other)

No 10-K data

Kilowatt-hour deliveries (other)

No 10-Q data

Kilowatt-hour sales (other)

No 10-Q data

Large hydroelectric generation share (other)

No 10-Q data

Lawsuits - Thomas/Koenigstein Fires (other)

No 10-K data

Lawsuits - Woolsey Fire (other)

No 10-K data

Lawsuits Filed (other)

No 10-K data

Lawsuits filed (other)

No 10-K data

Leased railcars (other)

No 10-Q data

Letters of credit issued (other)

Level 3 CRR fair value (other)

No 10-Q data

Level 3 derivative net liability (other)

No 10-Q data

Level 3 tolling fair value (other)

No 10-Q data

Leveraged Lease Investment (other)

No 10-Q data

Leveraged lease investment balance (other)

No 10-Q data

Leveraged lease investments (other)

No 10-Q data

Line circuit miles (other)

No 10-Q data

Lines of credit availability (other)

No 10-K data

Load factor (other)

No 10-K data

Long-Term Debt (other)

No 10-K data

Long-term Debt (other)

No 10-Q data

Long-term debt carrying value (other)

No 10-K data

Long-term debt fair value (other)

Long-term debt maturities (other)

Loy Yang B hedged output (other)

No 10-K data

MEHC Interest Coverage Ratio (other)

No 10-K data

MEHC interest coverage ratio (other)

No 10-K data

MHI arbitration claim (other)

MHI counterclaim (other)

No 10-Q data

MHI invoices submitted (other)

No 10-Q data

MHI stated liability limit (other)

No 10-Q data

Mandated power purchase premium (other)

No 10-K data

Margin and collateral deposits (other)

No 10-K data

Market energy price (other)

No 10-K data

Market power costs (other)

No 10-K data

Market value of common equity (other)

No 10-Q data

Material remediation sites (other)

No 10-K data

Maximum additional dividend (other)

No 10-K data

Maximum additional dividend capacity (other)

No 10-K data

Medium/heavy-duty vehicles electrified (other)

No 10-Q data

Memorandum account costs (other)

No 10-K data

Mesa Substation project cost (other)

No 10-Q data

Mohave Generating Station sale price (other)

No 10-K data

Mohave refund (other)

No 10-K data

Money market funds (other)

No 10-K data

Montecito Mudslides Structures Damaged (other)

No 10-K data

Montecito Mudslides Structures Destroyed (other)

No 10-K data

Montecito Mudslides fatalities (other)

No 10-K data

Montecito Mudslides structures destroyed (other)

No 10-K data

Moody's Baa utility bond yield (other)

No 10-K data

NAPP coal price (other)

No 10-K data

NEIL claims submitted (other)

No 10-Q data

NEIL insurance claims submitted (other)

No 10-K data

NEIL insurance recoveries (other)

No 10-Q data

NEIL insurance settlement (other)

NOX allowance spot price (other)

No 10-K data

NOx allowance average purchase price (other)

No 10-K data

NOx allowance spot price (other)

No 10-K data

Natural gas derivative notional (other)

No 10-K data

Natural gas derivative notional volume (other)

No 10-Q data

Natural gas generation share (other)

No 10-Q data

Natural gas hedge (other)

No 10-Q data

Natural gas hedge notional (other)

No 10-K data

Natural gas hedge notional volume (other)

No 10-K data

Natural gas notional volume (other)

No 10-K data

Negotiated power capacity (other)

No 10-K data

Net cash provided by financing activities (other)

No 10-K data

Net cash provided by operating activities (other)

No 10-K data

Net cash used in financing activities (other)

No 10-K data

Net cash used in investing activities (other)

No 10-K data

Net credit risk exposure (other)

No 10-K data

Net derivative fair value (other)

No 10-K data

Net derivative liability (other)

No 10-K data

Net operating loss carryforwards (other)

No 10-Q data

Net purchases of nuclear decommissioning trust investments (other)

No 10-K data

Net regulatory balancing account overcollections (other)

No 10-K data

Net stranded assets (other)

No 10-K data

Non-core items (other)

No 10-K data

Northern Illinois Hub price (other)

No 10-K data

Notional volume (other)

No 10-K data

Notional volume of congestion revenue rights (other)

No 10-K data

Notional volume of electricity derivatives (other)

No 10-K data

Notional volume of natural gas derivatives (other)

No 10-K data

Notional volume of tolling arrangements (other)

No 10-K data

Nuclear Decommissioning Trust (other)

No 10-K data

Nuclear Decommissioning Trust Assets (other)

Nuclear Decommissioning Trust Balance (other)

No 10-Q data

Nuclear Decommissioning Trusts (other)

Nuclear asset retirement obligation (other)

No 10-K data

Nuclear assets rate of return (other)

No 10-K data

Nuclear assets return on investment (other)

No 10-K data

Nuclear authorized return (other)

No 10-K data

Nuclear decommissioning cost estimate (other)

Nuclear decommissioning costs (other)

No 10-K data

Nuclear decommissioning estimate (other)

No 10-K data

Nuclear decommissioning estimated cost (other)

No 10-K data

Nuclear decommissioning provision (other)

No 10-Q data

Nuclear decommissioning trust (other)

Nuclear decommissioning trust assets (other)

No 10-K data

Nuclear decommissioning trust balance (other)

No 10-Q data

Nuclear decommissioning trust contribution (other)

No 10-K data

Nuclear decommissioning trust contributions (other)

No 10-K data

Nuclear decommissioning trust earnings (other)

No 10-K data

Nuclear decommissioning trust fair value (other)

No 10-K data

Nuclear decommissioning trust funds (other)

Nuclear decommissioning trust investments (other)

Nuclear decommissioning trust value (other)

No 10-K data

Nuclear decommissioning trusts (other)

No 10-K data

Nuclear decommissioning trusts fair value (other)

No 10-K data

Nuclear fuel at amortized cost (other)

No 10-Q data

Nuclear generation share (other)

No 10-Q data

Nuclear insurance annual deferred premium limit (other)

No 10-K data

Nuclear insurance coverage (other)

No 10-Q data

Nuclear insurance maximum deferred premium (other)

No 10-K data

Nuclear insurance maximum exposure (other)

No 10-Q data

Nuclear insurance primary (other)

No 10-K data

Nuclear insurance primary coverage (other)

No 10-K data

Nuclear insurance public liability limit (other)

No 10-K data

Nuclear investment impairment (other)

No 10-K data

Nuclear public liability limit (other)

No 10-K data

Nuclear retrospective premium (other)

No 10-Q data

Nuclear return (other)

No 10-K data

Nuclear return on equity (other)

No 10-K data

Nuclear trust contributions (other)

No 10-Q data

Nuclear trust decommissioning disbursements (other)

No 10-Q data

Nuclear trust deferred taxes (other)

No 10-Q data

Nuclear trust equity investments in US (other)

No 10-Q data

Nuclear trust income taxes (other)

No 10-Q data

Nuclear trust interest and dividends (other)

No 10-Q data

Nuclear trust investments (other)

No 10-Q data

Nuclear trust net of taxes (other)

No 10-Q data

Nuclear trust other-than-temporary impairments (other)

No 10-Q data

Nuclear trust realized gains (other)

No 10-Q data

Nuclear trust unrealized gains (other)

No 10-Q data

Nuclear trust unrealized losses (other)

No 10-Q data

Number of Reportable Segments (other)

Operating cash flow (other)

No 10-Q data

Operating facilities (other)

No 10-Q data

Operating power facilities (other)

No 10-Q data

Operating power plants (other)

No 10-Q data

Operating power plants (EME) (other)

No 10-Q data

Operating power projects (other)

No 10-Q data

Operating projects (other)

No 10-Q data

Operating revenue by customer class (other)

No 10-Q data

Other expenses (other)

No 10-K data

Other power purchase agreements (other)

No 10-Q data

Own generation share (other)

No 10-Q data

Owned capacity fuel mix (other)

No 10-Q data

Owned capacity mix (other)

No 10-Q data

PBOP Benefit Obligation (other)

No 10-Q data

PBOP Level 3 investments (other)

No 10-Q data

PBOP VEBA trust Level 3 investments (other)

No 10-Q data

PBOP VEBA trust investments (other)

No 10-Q data

PBOP actual return on assets (other)

No 10-Q data

PBOP actuarial gain (other)

No 10-Q data

PBOP benefit obligation (other)

No 10-Q data

PBOP benefit payments (other)

No 10-Q data

PBOP benefits paid (other)

No 10-Q data

PBOP contributions (other)

No 10-K data

PBOP discount rate (other)

No 10-Q data

PBOP discount rate for obligations (other)

No 10-Q data

PBOP employer contributions (other)

No 10-Q data

PBOP expected return on assets (other)

No 10-Q data

PBOP expense (other)

PBOP funded status (other)

No 10-Q data

PBOP health care trend rate (other)

No 10-Q data

PBOP interest cost (other)

No 10-Q data

PBOP mortality table impact (other)

No 10-Q data

PBOP participant contributions (other)

No 10-Q data

PBOP plan actual returns (other)

No 10-Q data

PBOP plan assets (other)

No 10-Q data

PBOP plan assets in US (other)

No 10-Q data

PBOP plan contributions (other)

No 10-Q data

PBOP regulatory asset (other)

No 10-Q data

PBOP service cost (other)

No 10-Q data

PBOP unrecognized prior service credit to amortize (other)

No 10-Q data

PJM West Hub Forward Energy Price (other)

No 10-K data

PJM West Hub price (other)

No 10-K data

PJM market price (other)

No 10-K data

PJM revenue share (other)

PRB coal price (other)

No 10-K data

PROACT balance (other)

No 10-K data

PSPS Customer Minutes Interrupted (other)

No 10-Q data

PSPS Events (other)

No 10-Q data

PSPS activations (other)

No 10-Q data

PSPS customer minutes interrupted (other)

No 10-Q data

PSPS customers impacted (other)

PSPS events (other)

PSPS events initiated (other)

PX Generation Sales (other)

No 10-K data

PX Purchases (other)

No 10-K data

PX forward purchase limit (other)

No 10-K data

Paiton construction completion (other)

No 10-K data

Paiton interim capacity payments received (other)

No 10-K data

Paiton project completion (other)

No 10-K data

Paiton project ownership interest (other)

No 10-K data

Palo Verde Ownership Interest (other)

No 10-K data

Palo Verde and Four Corners sale price (other)

No 10-K data

Palo Verde net book value (other)

No 10-Q data

Palo Verde ownership interest (other)

No 10-Q data

Palo Verde steam generator replacement cost (other)

No 10-K data

Palo Verde sunk cost (other)

No 10-K data

Payments to VIE projects (other)

No 10-K data

Peak Demand (other)

No 10-Q data

Peak demand (other)

No 10-Q data

Peaker plants in service (other)

No 10-Q data

Pending Eaton Fire lawsuits (other)

No 10-K data

Pending lawsuits (other)

No 10-K data

Pension Benefit Obligation (other)

No 10-Q data

Pension Level 3 investments (other)

No 10-Q data

Pension accumulated benefit obligation (other)

No 10-Q data

Pension actual return on assets (other)

No 10-Q data

Pension actuarial gain (other)

No 10-Q data

Pension and PBOP net income (other)

No 10-K data

Pension and PBOP regulatory asset (other)

No 10-Q data

Pension benefit obligation (other)

No 10-Q data

Pension benefit payments (other)

No 10-Q data

Pension benefits paid (other)

No 10-Q data

Pension contributions (other)

No 10-K data

Pension cumulative regulatory asset (other)

No 10-Q data

Pension discount rate (other)

No 10-Q data

Pension discount rate for obligations (other)

No 10-Q data

Pension employer contributions (other)

No 10-Q data

Pension expected return on assets (other)

No 10-Q data

Pension expense (other)

Pension expense under accounting standards (other)

No 10-Q data

Pension interest cost (other)

No 10-Q data

Pension mortality table impact (other)

No 10-Q data

Pension plan Level 3 investments (other)

No 10-Q data

Pension plan actual returns (other)

No 10-Q data

Pension plan asset allocation (other)

No 10-Q data

Pension plan asset decline (other)

No 10-K data

Pension plan assets (other)

No 10-Q data

Pension plan assets in US (other)

No 10-Q data

Pension plan contributions (other)

Pension plan funded status (other)

No 10-Q data

Pension plan master trust investments (other)

No 10-Q data

Pension projected benefit obligation (other)

No 10-Q data

Pension regulatory adjustment (other)

No 10-Q data

Pension regulatory asset (other)

No 10-Q data

Pension service cost (other)

No 10-Q data

Pension unrecognized net loss to amortize (other)

No 10-Q data

Pension unrecognized prior service cost to amortize (other)

No 10-Q data

Pensions and benefits liability (other)

No 10-Q data

Pensions and other postretirement benefits regulatory asset (other)

No 10-K data

Performance shares nonvested (other)

No 10-K data

Plaintiffs (other)

No 10-K data

Plaintiffs outstanding (other)

No 10-K data

Plaintiffs settled (other)

No 10-K data

Planned CPUC wildfire cost recovery (other)

No 10-Q data

Pole loading rate base (other)

No 10-Q data

Poles (other)

No 10-Q data

Pollution-control bonds issued (other)

No 10-K data

Pollution-control bonds redeemed (other)

No 10-K data

Pollution-control bonds reissued (other)

No 10-K data

Population in service territory (other)

No 10-Q data

Population served (other)

No 10-Q data

Post-2018 insurance recoveries (other)

No 10-K data

Post-2018 remaining loss estimate (other)

No 10-K data

Post-2018 wildfire losses accrued (other)

No 10-K data

Postretirement benefit contributions (other)

No 10-K data

Postretirement benefit plan asset decline (other)

No 10-K data

Postretirement benefit plan funded status (other)

No 10-Q data

Potential Collateral Requirements (other)

No 10-K data

Potential collateral requirements (other)

No 10-K data

Potential environmental cost excess (other)

No 10-K data

Potential environmental cost increase (other)

No 10-K data

Potential transition costs (other)

No 10-K data

Potential workforce reduction charge (other)

No 10-K data

Power contract classified as capital lease reduction (other)

No 10-K data

Power poles damaged (other)

No 10-K data

Power projects (other)

No 10-Q data

Power purchase agreements (other)

No 10-Q data

Power purchase contracts (other)

No 10-Q data

Power source mix (other)

No 10-Q data

Power supply mix (other)

No 10-Q data

Preference stock issued (other)

No 10-K data

Preferred and preference stock (other)

No 10-Q data

Preferred stock redemption requirements (other)

No 10-K data

Proceeds from sale of nuclear decommissioning trust investments (other)

No 10-K data

Project financing outstanding (other)

No 10-K data

Projected ERRA undercollection (other)

No 10-K data

Projected capital expenditures (other)

No 10-K data

Projected capital requirements (other)

No 10-K data

Projected construction expenditures (other)

No 10-K data

Projected environmental capital expenditures (other)

No 10-K data

Projected nuclear decommissioning cost (other)

No 10-K data

Property damage insurance coverage (other)

No 10-K data

Property damage insurance limit (other)

No 10-K data

Proposed base rate revenue requirement (other)

No 10-K data

Proposed rate reduction (other)

No 10-K data

Proposed return on equity (other)

No 10-K data

Provision for uncollectible accounts (other)

No 10-K data

Public Float (other)

No 10-Q data

Public float (other)

No 10-Q data

Public float value (other)

No 10-Q data

Public purpose and energy efficiency overcollection (other)

No 10-Q data

Public safety power shutoffs (other)

No 10-Q data

Purchases from PX (other)

No 10-K data

Purchases of nuclear decommissioning trust investments (other)

No 10-K data

QF capacity under settlement (other)

No 10-K data

QF contract overpayment (other)

No 10-K data

QF energy under settlement (other)

No 10-K data

QF power purchase agreements (other)

No 10-Q data

QF power purchase cost premium (other)

No 10-K data

QF power purchase premium (other)

No 10-Q data

QF power-purchase contracts (other)

Qualifying facilities power premium (other)

No 10-K data

Qualifying facility contracts (other)

RA capacity procured (other)

No 10-Q data

Racially/ethnically diverse workforce share (other)

No 10-Q data

Rate Base (other)

Rate Base Forecast (other)

No 10-K data

Rate base (other)

Rate base forecast (other)

No 10-K data

Rate increase (other)

No 10-K data

Rate increase impact (other)

No 10-K data

Rate of compensation increase (other)

No 10-Q data

Rate reduction bonds authorized (other)

No 10-K data

Rate reduction goal (other)

No 10-K data

Rate reduction notes outstanding (other)

No 10-K data

Realized derivative losses (other)

No 10-Q data

Realized losses on derivatives (other)

No 10-K data

Recorded remediation liability (other)

No 10-K data

Recourse debt to recourse capital (other)

No 10-K data

Recourse debt to recourse capital ratio (other)

No 10-K data

Recoveries in excess of ARO liabilities (other)

No 10-K data

Recoveries in excess of ARO regulatory liability (other)

No 10-Q data

Regulatory Assets (other)

Regulatory Assets - Wildfire Insurance (other)

No 10-K data

Regulatory Assets - Wildfire Mitigation (other)

No 10-K data

Regulatory Liabilities (other)

Regulatory asset write-down (other)

No 10-Q data

Regulatory assets (other)

Regulatory assets - Wildfire Insurance (other)

No 10-K data

Regulatory assets - Wildfire Mitigation (other)

No 10-K data

Regulatory balancing account overcollections (other)

No 10-Q data

Regulatory balancing account undercollections (other)

No 10-K data

Regulatory balancing accounts liability (other)

No 10-K data

Regulatory balancing accounts net over-collections (other)

No 10-Q data

Regulatory liabilities (other)

Remaining wildfire claims estimate (other)

No 10-Q data

Remaining wildfire loss estimate (other)

No 10-K data

Remediation sites (other)

Renewable energy contract commitments (other)

No 10-Q data

Renewable energy contracts (other)

No 10-Q data

Rent service coverage ratio (other)

No 10-K data

Replacement power market costs (other)

No 10-K data

Requested ROE (other)

No 10-K data

Requested cost of long-term debt (other)

No 10-K data

Requested cost of preferred equity (other)

No 10-K data

Requested return on equity (other)

No 10-K data

Requested return on rate base (other)

No 10-K data

Requested revenue requirement (other)

No 10-K data

Requested weighted average return on rate base (other)

No 10-K data

Residential bill reduction (other)

No 10-K data

Residual CTC revenue in TCBA (other)

No 10-K data

Residual net short (other)

No 10-K data

Restoration Capital Expenditures (other)

No 10-K data

Retail Revenue (other)

No 10-K data

Retail billed and unbilled revenue (other)

Retail revenue (other)

No 10-K data

Retail sales share (other)

No 10-K data

Retail sales share of revenue (other)

No 10-K data

Retail sales volume change (other)

No 10-K data

Retail share of operating revenue (other)

No 10-K data

Retail share of revenue (other)

No 10-K data

Retrospective premium adjustment limit (other)

No 10-K data

Return on Common Equity (other)

No 10-K data

Return on common equity (other)

Return on equity (other)

No 10-K data

Return on rate base (other)

No 10-K data

Revenue by customer class (other)

No 10-Q data

Revenue deferral (other)

No 10-K data

Revenue mix by customer class (other)

No 10-Q data

Revenue requirement request (other)

No 10-K data

Revenue subject to refund (other)

No 10-K data

Revolver availability (other)

No 10-K data

SCE Common Equity Component (other)

No 10-K data

SCE Common Equity to Total Capitalization (other)

No 10-K data

SCE Dividend Capacity (other)

No 10-K data

SCE additional bond issuance capacity (other)

No 10-K data

SCE additional dividend capacity (other)

No 10-K data

SCE additional mortgage bond capacity (other)

No 10-K data

SCE additional preferred stock capacity (other)

No 10-K data

SCE annual nuclear incident payment limit (other)

No 10-K data

SCE available credit facility (other)

No 10-K data

SCE capacity mix (other)

No 10-Q data

SCE capital expenditures (other)

No 10-K data

SCE cash on hand (other)

No 10-K data

SCE cash reserves (other)

No 10-K data

SCE collateral posted (other)

No 10-K data

SCE common equity component (other)

No 10-Q data

SCE common equity ratio (other)

No 10-K data

SCE common stock outstanding (other)

No 10-Q data

SCE debt to capitalization (other)

No 10-K data

SCE debt to capitalization ratio (other)

No 10-K data

SCE debt to total capitalization (other)

No 10-K data

SCE debt-to-capital ratio (other)

No 10-K data

SCE dividend capacity (other)

SCE dividends paid to Edison International (other)

No 10-Q data

SCE dividends paid to parent (other)

No 10-Q data

SCE energy source mix (other)

No 10-Q data

SCE max nuclear incident payment (other)

No 10-K data

SCE maximum nuclear incident payment (other)

No 10-K data

SCE nuclear insurance maximum (other)

No 10-K data

SCE peak demand (other)

No 10-Q data

SCE power source mix (other)

No 10-Q data

SCE preferred stock capacity (other)

No 10-K data

SCE preferred stock issuance capacity (other)

No 10-K data

SCE pro rata capacity share (other)

No 10-Q data

SCE rate base (other)

No 10-Q data

SCE residual net short (other)

No 10-K data

SCE restructuring implementation costs (other)

No 10-K data

SCE return on common equity (other)

No 10-K data

SCE return on rate base (other)

No 10-K data

SCE revenue mix (other)

No 10-Q data

SCE revenue mix by customer class (other)

No 10-Q data

SCE service territory area (other)

SCE share of NEIL insurance claims (other)

No 10-K data

SCE shares outstanding (other)

No 10-K data

SCE system average rate (other)

SCE transition costs (other)

No 10-K data

SCE unpaid obligations (other)

No 10-K data

SCE unpaid overdue obligations (other)

No 10-K data

SCE-owned capacity mix (other)

No 10-Q data

SO2 allowance average purchase price (other)

No 10-K data

SO2 allowance price (other)

No 10-K data

SO2 allowance spot price (other)

No 10-K data

Sales to Exelon Generation (other)

No 10-K data

Sales volume decrease (other)

No 10-K data

San Onofre ARO liability (other)

No 10-K data

San Onofre Ownership Interest (other)

No 10-K data

San Onofre Regulatory Asset (other)

No 10-K data

San Onofre Unit 1 decommissioning expenditures (other)

No 10-Q data

San Onofre Unit 2 tubes removed (other)

No 10-K data

San Onofre Unit 3 tubes removed (other)

No 10-K data

San Onofre decommissioning cost estimate (other)

No 10-Q data

San Onofre decommissioning costs funded (other)

No 10-Q data

San Onofre decommissioning trust funds (other)

No 10-K data

San Onofre incremental pricing rate (other)

No 10-K data

San Onofre inspection and repair costs (other)

No 10-Q data

San Onofre lost revenue (other)

No 10-K data

San Onofre net investment (other)

No 10-K data

San Onofre operating cost rate (other)

No 10-K data

San Onofre regulatory asset (other)

San Onofre regulatory liability (other)

No 10-K data

San Onofre remaining investment (other)

No 10-K data

San Onofre replacement power costs (other)

No 10-Q data

San Onofre steam generator tubes removed (other)

No 10-K data

San Onofre trust disbursements (other)

No 10-Q data

San Onofre trust reimbursement (other)

No 10-Q data

Secured leverage ratio (other)

No 10-K data

Securitized bonds issued (other)

Self-generation share (other)

No 10-Q data

Self-insurance amounts collected (other)

No 10-K data

Self-insurance collected (other)

No 10-K data

Self-insurance collections (other)

No 10-K data

Self-insurance coverage (other)

No 10-K data

Self-insurance fund (other)

No 10-K data

Self-supplied power share (other)

No 10-Q data

Senior rent service coverage (other)

No 10-K data

Senior rent service coverage ratio (other)

No 10-K data

Service Area (other)

No 10-Q data

Service Territory Area (other)

No 10-K data

Service area (other)

Service area population (other)

No 10-Q data

Service territory (other)

No 10-Q data

Service territory area (other)

Service territory in high fire risk areas (other)

No 10-K data

Service territory population (other)

No 10-Q data

Settled individual plaintiffs (other)

No 10-K data

Severance costs (other)

No 10-Q data

Severance liability (other)

No 10-K data

Severance payments (other)

No 10-Q data

Share of state electricity generation (other)

No 10-K data

Shareholders of record (other)

No 10-Q data

Shares of common stock outstanding (other)

No 10-Q data

Shares outstanding (other)

Shares remaining for future issuance (other)

No 10-Q data

Shares repurchased (other)

No 10-K data

Short-term Debt (other)

No 10-Q data

Short-term debt (other)

Short-term debt interest rate (other)

No 10-K data

Small hydroelectric generation share (other)

No 10-Q data

Smart Meters Installed (other)

No 10-Q data

Smart meter deployment (other)

No 10-Q data

Smart meter deployment plan (other)

No 10-Q data

Smart meters (planned) (other)

No 10-Q data

Smart meters installed (other)

Smart meters planned (other)

No 10-Q data

Solar generation share (other)

No 10-Q data

Sources of power (other)

No 10-Q data

Steam generator costs (other)

No 10-K data

Steam generator project costs (other)

No 10-K data

Steam generator project spend (other)

No 10-K data

Steam generator replacement spend (other)

No 10-K data

Steam generator tubes plugged (other)

No 10-K data

Steam generator tubes removed (other)

No 10-K data

Stock options exercisable (other)

No 10-K data

Stock options outstanding (other)

Stock repurchased (other)

No 10-K data

Stock-based compensation expense (other)

No 10-Q data

Storm Lake Investment (other)

No 10-K data

Storm Lake Outstanding Loans (other)

No 10-K data

Structures damaged (other)

No 10-K data

Structures destroyed (other)

No 10-K data

Substations (other)

No 10-Q data

Superfund site liability percentage (other)

No 10-K data

System average electric rate (other)

No 10-K data

System average electricity rate (other)

No 10-K data

System average rate (other)

TAMA and pole loading regulatory liability (other)

No 10-Q data

TCBA undercollection (other)

No 10-K data

TOU rate customers (other)

No 10-Q data

TOU rate enrollment (other)

No 10-Q data

TRA undercollection balance (other)

No 10-K data

Tangible net worth (other)

No 10-K data

Target payout ratio (other)

No 10-Q data

Tax credit carryforwards (other)

No 10-Q data

Tax loss and credit carryforwards (other)

No 10-Q data

Tax repair deduction regulatory liability (other)

No 10-Q data

Tehachapi direct expenditures (other)

No 10-Q data

Tehachapi project cost estimate (other)

No 10-Q data

Thomas Fire Acres Burned (other)

No 10-K data

Thomas Fire Structures Damaged (other)

No 10-K data

Thomas Fire Structures Destroyed (other)

No 10-K data

Thomas Fire acres burned (other)

No 10-K data

Thomas Fire structures destroyed (other)

No 10-K data

Thomas/Koenigstein Fire lawsuits (other)

No 10-K data

Time-of-use rate adoption (other)

No 10-Q data

Tolling arrangement notional (other)

No 10-K data

Tolling arrangement notional volume (other)

No 10-Q data

Tolling arrangements notional volume (other)

No 10-K data

Tolling notional volume (other)

No 10-K data

Total Segment Assets (other)

No 10-K data

Total assets (other)

No 10-K data

Total authorized rate base (other)

No 10-Q data

Total available liquidity (other)

No 10-K data

Total capital program (other)

No 10-K data

Total company rate base (other)

No 10-K data

Total contractual obligations (other)

No 10-Q data

Total debt (other)

No 10-K data

Total estimated wildfire losses (other)

No 10-K data

Total lease cost (other)

No 10-K data

Total nuclear decommissioning cost estimate (other)

No 10-Q data

Total stranded assets (other)

No 10-K data

Transformers (other)

No 10-Q data

Transformers damaged (other)

No 10-K data

Transition capacity contracts (other)

No 10-K data

Transition cost estimate (other)

No 10-K data

Transition costs estimate (other)

No 10-K data

Transition revenue account undercollection (other)

No 10-K data

Transition-related balancing accounts undercollections (other)

No 10-K data

Transmission Capex (other)

No 10-Q data

Transmission authorized return (other)

No 10-K data

Transmission revenue requirement (other)

No 10-K data

Transmission revenue requirement increase (other)

No 10-K data

Transmission revenue requirement increase percentage (other)

No 10-K data

Transmission substations (other)

No 10-Q data

Transportation electrification vehicles (other)

No 10-K data

Trees to be removed (other)

No 10-K data

Trust securities issued (other)

No 10-K data

Tubes removed from service (other)

No 10-K data

Turbine purchase commitments (other)

No 10-Q data

Turnover Rate (other)

No 10-Q data

Turnover rate (other)

No 10-Q data

Unamortized investments net (other)

No 10-K data

Unamortized loss on reacquired debt (other)

Uncollectible accounts allowance (other)

No 10-K data

Underground circuit miles (other)

No 10-Q data

Unit 2 tubes removed (other)

No 10-K data

Unit 3 tubes removed (other)

No 10-K data

Unpaid and overdue obligations (other)

No 10-K data

Unrealized derivative losses (other)

No 10-Q data

Unrealized losses on derivatives (other)

No 10-K data

Unrecognized PBOP costs (other)

No 10-Q data

Unrecognized pension costs (other)

No 10-Q data

Unrecognized tax benefits (other)

No 10-Q data

Utility Property, Plant and Equipment (other)

No 10-K data

Utility poles (other)

No 10-Q data

Utility property plant and equipment (other)

No 10-Q data

Utility-owned generation (other)

No 10-Q data

Utility-owned generation share (other)

No 10-Q data

Value at Risk (other)

No 10-K data

Value at risk (other)

No 10-K data

Vehicles electrified (other)

No 10-Q data

Voluntary Turnover Rate (other)

No 10-Q data

Voluntary retirement acceptances (other)

No 10-Q data

Votes for Carl F. Huntsinger (other)

No 10-K data

Votes for Charles D. Miller (other)

No 10-K data

Votes for Daniel M. Tellep (other)

No 10-K data

Votes for Edward Zapanta (other)

No 10-K data

Votes for James M. Rosser (other)

No 10-K data

Votes for Joan C. Hanley (other)

No 10-K data

Votes for John E. Bryson (other)

No 10-K data

Votes for Luis G. Nogales (other)

No 10-K data

Votes for Robert H. Smith (other)

No 10-K data

Votes for Ronald L. Olson (other)

No 10-K data

Votes for Stephen E. Frank (other)

No 10-K data

Votes for Thomas C. Sutton (other)

No 10-K data

Votes for Warren Christopher (other)

No 10-K data

Votes withheld for Carl F. Huntsinger (other)

No 10-K data

Votes withheld for Charles D. Miller (other)

No 10-K data

Votes withheld for Daniel M. Tellep (other)

No 10-K data

Votes withheld for Edward Zapanta (other)

No 10-K data

Votes withheld for James M. Rosser (other)

No 10-K data

Votes withheld for Joan C. Hanley (other)

No 10-K data

Votes withheld for John E. Bryson (other)

No 10-K data

Votes withheld for Luis G. Nogales (other)

No 10-K data

Votes withheld for Robert H. Smith (other)

No 10-K data

Votes withheld for Ronald L. Olson (other)

No 10-K data

Votes withheld for Stephen E. Frank (other)

No 10-K data

Votes withheld for Thomas C. Sutton (other)

No 10-K data

Votes withheld for Warren Christopher (other)

No 10-K data

Weighted Average Return on Rate Base (other)

No 10-K data

Weighted average diluted shares (other)

No 10-K data

Weighted average rate base (other)

Weighted average return on rate base (other)

Weighted average shares (other)

No 10-K data

Weighted average shares outstanding (other)

No 10-K data

Weighted-average rate base (other)

No 10-K data

Weighted-average shares (other)

No 10-K data

Weighted-average shares outstanding (other)

No 10-K data

West of Devers project cost (other)

No 10-Q data

Wildfire Fund Receivable (other)

No 10-K data

Wildfire Fund claims-paying capacity (other)

No 10-K data

Wildfire Fund coverage period (other)

No 10-K data

Wildfire Fund liability cap (other)

No 10-K data

Wildfire Insurance Coverage (other)

No 10-K data

Wildfire Insurance Fund Contribution (other)

No 10-K data

Wildfire Insurance Fund Contributions (other)

No 10-K data

Wildfire Insurance Fund amortization life (other)

No 10-K data

Wildfire Insurance Fund capacity (other)

No 10-K data

Wildfire Insurance Fund contribution (other)

No 10-K data

Wildfire Insurance Fund contributions (other)

Wildfire Insurance Fund life (other)

No 10-K data

Wildfire Insurance Self-Insured Retention (other)

No 10-K data

Wildfire Mitigation Capex (other)

No 10-Q data

Wildfire accrued losses (other)

No 10-K data

Wildfire claim charges (other)

No 10-K data

Wildfire claims accrued (other)

Wildfire claims liabilities (other)

No 10-K data

Wildfire claims paid (other)

No 10-K data

Wildfire cumulative charges (other)

No 10-K data

Wildfire insurance coverage (other)

Wildfire insurance coverage limit (other)

No 10-K data

Wildfire insurance expense (other)

Wildfire insurance fund contributions (other)

Wildfire insurance fund reimbursement cap (other)

No 10-Q data

Wildfire insurance premium (other)

No 10-K data

Wildfire insurance recoveries (other)

No 10-K data

Wildfire insurance regulatory asset (other)

No 10-K data

Wildfire insurance regulatory assets (other)

No 10-K data

Wildfire insurance self-insured retention (other)

No 10-K data

Wildfire lawsuit plaintiffs (other)

No 10-K data

Wildfire lawsuits (other)

No 10-K data

Wildfire liability cap (other)

No 10-K data

Wildfire memorandum accounts (other)

No 10-K data

Wildfire mitigation capex (other)

No 10-Q data

Wildfire mitigation capital expenditures (other)

No 10-K data

Wildfire mitigation regulatory assets (other)

No 10-K data

Wildfire plaintiffs (other)

No 10-K data

Wildfire regulatory assets (other)

Wildfire remaining losses (other)

No 10-K data

Wildfire restoration capital expenditures (other)

No 10-K data

Wildfire self-insurance coverage (other)

No 10-K data

Wildfire self-insurance fund (other)

No 10-K data

Wildfire settlement payments (other)

Wildfire settlements paid (other)

No 10-K data

Wildfire-Related Claims Liability (other)

No 10-K data

Wildfire-related FERC recoveries (other)

No 10-Q data

Wildfire-related claims estimated losses (other)

No 10-Q data

Wildfire-related claims expense (other)

No 10-K data

Wildfire-related claims liability (other)

No 10-K data

Wildfire-related claims paid (other)

No 10-Q data

Wildfire-related insurance recoveries (other)

No 10-Q data

Wildfire-related memorandum accounts (other)

No 10-K data

Wildfire-related regulatory assets (other)

No 10-K data

Wind Turbine Commitments (other)

No 10-Q data

Wind Turbine Commitments Value (other)

No 10-Q data

Wind development pipeline (other)

Wind turbine purchase commitments (other)

No 10-Q data

Wind turbines committed (other)

No 10-Q data

Wind turbines in storage (other)

No 10-Q data

Wind turbines purchased (other)

No 10-Q data

Wind turbines secured (other)

Wind turbines under agreement (other)

No 10-Q data

Woolsey Fire lawsuits (other)

No 10-K data

Woolsey Fire plaintiffs (other)

No 10-K data

Workforce reduction (other)

No 10-Q data

Y2K readiness progress (other)

No 10-Q data

Year 2000 Costs Expended (other)

No 10-K data

Year 2000 costs expended (other)

No 10-K data

Year 2000 estimated total cost (other)

No 10-K data

Year 2000 program cost estimate (other)

No 10-K data

Year 2000 remediation costs (other)

No 10-K data

Year 2000 remediation progress (other)

No 10-K data

Year 2000 total estimated costs (other)

No 10-K data

kWh sales growth (other)

No 10-K data

Charge Ready Transport Sites (properties)

Renewable Portfolio (renewable_capacity)

RPS eligible supply portfolio (renewable_energy_pct)

No 10-Q data

Contractor DART Rate (safety_incidents)

No 10-Q data

SCE Common Stock Outstanding (shares)

No 10-Q data

Common stock outstanding (shares_outstanding)

No 10-Q data

Service territory area (square_footage)

Transmission lines (transmission_miles)

Contractor EEI SIF Rate (trir)

No 10-Q data

Charge Ports Deployed (units_shipped)

No 10-Q data

Equivalent Availability (utilization_rate)

Human capital disclosures. Workforce totals and demographics are point-in-time. Flow metrics use the year-to-date period for 10-Q and full year for 10-K. Workforce actions (RIFs, restructurings, acquisition-related changes) are listed in the table at the bottom.

Workforce Totals

No 10-Q data
No 10-Q data
No 10-Q data

Demographics

No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data

Workforce Breakdowns

No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data

HCM Metrics — Point-in-Time

No point-in-time HCM metrics found.

HCM Metrics — Flow (Annual / YTD)

No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data
No 10-Q data

Workforce Actions

Period EndTypeStatusAffected% WorkforceAnnouncedExpected CompletionGeographySegment / FunctionChargeSourceNote
2026-06-30divestiture_reductioncompleted2026-06-30Trio (Edison Energy, LLC)USD 5 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Edison International completed the disposition of Trio in Q2 2026. Recognized $5 million in employee-related expenses. Headcount not disclosed.
2025-12-31restructuringcompleted2024-12-312024-12-31United StatesCorporateUSD 50 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Severance costs recorded in 2024 due to reductions in workforce. Disclosed as non-core item in 2024 comparison.
2025-09-30restructuringcompletedSouthern CaliforniaCorporate / GeneralUSD 44 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Severance costs recorded in 2024 due to reductions in workforce. The 2025 filing notes a decrease in O&M expense due to these prior-year costs, indicating the action was completed in the prior period.
2024-12-31reduction_in_forcein_progress2024California (SCE service area)SCE (regulated electric utility)USD 53 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Severance recorded for fiscal 2024 due to current and probable reductions in workforce; $50 million net of a $3 million expected FERC recovery per MD&A ($36 million after-tax). Affected employee count not disclosed.
2024-12-31reduction_in_forcecompletedUnited StatesSouthern California Edison CompanyUSD 53 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
SCE recorded estimated severance costs of $53 million for FY2024 due to current and probable reductions in workforce. Partially offset by $3 million expected FERC recovery (net charge $50 million). Number of employees affected not disclosed.
2024-12-31restructuringcompleted20242024-12-31United StatesCorporateUSD 53 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Severance costs recorded due to current and probable reductions in workforce.
2024-12-31restructuringcompleted2024-01-012024-12-31United StatesCorporateUSD 50 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Severance costs recorded due to current and probable reductions in workforce.
2024-09-30restructuringin_progress2024-07-01United StatesSouthern California Edison CompanyUSD 47 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE recorded $47M gross severance in Q3 2024 for current and probable workforce reductions; MD&A non-core items show $44M net of expected FERC recovery. Number of employees affected not disclosed.
2024-09-30restructuringin_progress2024-09-30Southern CaliforniaCorporate / GeneralUSD 47 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE recorded estimated severance costs of $47 million during the third quarter of 2024 due to current and probable reductions in workforce. Employee count not disclosed.
2023-12-31othercompleted4,2002023-02Southern California (SCE service territory)SCE represented workforceItem_1_Business
f5-10k / GLM-5.3-flash-HTML
IBEW members ratified new collective bargaining agreements in February 2023 covering approximately 4,200 SCE employees; agreements run January 1, 2023 through December 31, 2025.
2023-12-31otherin_progressSouthern California (SCE service territory)Additional employee groups certified to IBEWItem_1_Business
f5-10k / GLM-5.3-flash-HTML
SCE continued negotiations for collective bargaining agreements with additional employee groups that had certified IBEW as their bargaining representative; affected headcount not disclosed.
2023-06-30restructuringcompletedUSD 14 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Organizational realignment charge of $14 million recorded in Q2 2022. No employee count disclosed.
2022-12-31restructuringcompletedSCEUSD 14 (millions)MD&A
f5-10k / GLM-5.3-flash-HTML
Pre-tax charge recorded in 2022 for organizational realignment services ($10 million after-tax), presented as a non-core item within SCE results; the number of employees affected is not disclosed.
2022-12-31acquisition_additioncompleted2022-10United Kingdom (Alfa Energy is UK-based; Edison Energy serves North America and Europe)Edison Energybusiness_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
Edison Energy acquired 100% of Alfa Energy Ltd. in October 2022 for total consideration of $22 million, including contingent consideration of up to $17 million; goodwill of $16 million recognized. Headcount added through the acquisition is not disclosed; Alfa Energy employees are excluded from 2022 safety and diversity metrics.
2022-12-31othercompleted3,9002023-022025-12-31California (SCE service territory)SCEItem_1_Business
f5-10k / GLM-5.3-flash-HTML
Union contract ratification disclosed as a post-year-end event in the FY2022 10-K: IBEW membership ratified new collective bargaining agreements covering approximately 3,900 SCE employees for the period January 1, 2023 through December 31, 2025.
2022-12-31restructuringcompletedUnited StatesCorporate / Organizational realignmentUSD 14 (millions)MD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Charge of $14 million ($10 million after-tax) recorded in 2022 for organizational realignment services; employee count not disclosed
2022-12-31acquisition_additioncompleted2022-10-01United KingdomEdison Energybusiness_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Edison Energy acquired 100% of Alfa Energy Ltd., an international energy and sustainability consultancy, for total consideration of $22 million including contingent consideration; headcount added not disclosed
2022-12-31othercompleted3,9002023-02-012025-12-31United StatesSCE — IBEW collective bargainingItem_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Subsequent event: IBEW membership ratified new collective bargaining agreements covering approximately 3,900 SCE employees for the period January 1, 2023 through December 31, 2025; ratified February 2023
2022-09-30restructuringcompletedUnited StatesSCEUSD 14 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Charge of $14M ($10M after-tax) for organizational realignment services recorded in nine months ended 2022; no employee count disclosed.
2022-09-30acquisition_additionannounced2022-10-01United KingdomEdison EnergyUSD 18 (millions)subsequent_events
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Edison Energy acquired an international energy and sustainability consultancy in October 2022 for $18M initial cash; headcount added not disclosed.
2022-09-30restructuringcompletedUSD 10 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Organizational realignment charge of $10 million recorded in the nine months ended September 30, 2022. No employee count disclosed.
2022-06-30restructuringin_progressUnited StatesSouthern California Edison CompanyUSD 14 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Pre-tax charge of $14M ($10M after-tax) for organizational realignment services; no employee count, announcement date, or completion timeline disclosed.
2022-06-30restructuringcompletedUSD 10 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Organizational realignment charge of $10 million recorded in Q2 2022. Employee count not disclosed.
2018-12-31divestiture_reductioncompleted2018-02-282018-04-16United StatesEdison Energy Group — SoCore Energy (distributed solar)USD 62 (millions)other
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Pre-tax loss of $62 million ($50 million after-tax) recognized on the sale; headcount removed through the disposition is not quantified in the filing.
2017-12-31reduction_in_forcecompletedCalifornia (SCE service territory)Southern California Edison Company (SCE)USD 1 (millions)other
f5-10k / GLM-5.3-flash-HTML
SCE incurred costs for extended retiree health care coverage attributable to a workforce reduction; $1 million of special termination benefits was recognized in 2017 PBOP expense. Filer's exact term is "reduction in workforce"; no affected headcount, announcement date, or program timeline is disclosed, and completion status is inferred from recognition of 2017 costs.
2017-09-30othercompleted3,900United States (southern California)Southern California Edison Companyother
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE and IBEW recently negotiated and IBEW ratified 3% annual wage increases for calendar years 2018 and 2019, effective 2017-10-02; agreements covering approximately 3,900 full-time employees expire 2019-12-31. No announcement date or affected-count beyond the covered-employee figure is stated.
2017-09-30otherannouncedUnited StatesEdison Energy Group (SoCore Energy / Edison Energy)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
During Q3 2017 Edison International completed a strategic review and will evaluate strategic options, including a potential sale of SoCore Energy, while consolidating management across Edison Energy Group; Edison Energy targets breakeven by end of 2019. No headcount affected, charge, or announcement date disclosed; held-for-sale accounting was not applied as sale within one year was not probable at 2017-09-30.
2016-12-31reduction_in_forcein_progressCalifornia (SCE service territory)Southern California Edison Company (SCE)USD 21 (millions)other
f5-10k / GLM-5.3-flash-HTML
During 2016 SCE increased the estimated impact of approved workforce reductions tied to productivity-improvement efforts. Severance accrual roll-forward shows $21 million of additions charged to costs and expenses, $40 million of payments, and a $3 million balance remaining at December 31, 2016. Number of employees affected and completion timeline not disclosed. Severance costs are recorded in operation and maintenance expense.
2016-12-31restructuringin_progressUnited States (Southern California)Southern California Edison CompanyUSD 21 (millions)other
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Approved workforce reductions supporting productivity and cost-structure goals; 2016 additions of $21M to the accrued severance liability (balance fell from $22M to $3M after $40M of payments). No employee count, announcement date, or completion date disclosed; charge is current-fiscal-year activity only.
2016-12-31restructuringcompleted2016-12-312016-12-31CaliforniaSouthern California Edison CompanyUSD 21 (millions)restructuring_footnote
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
SCE increased estimated impact for approved workforce reductions during the year ended Dec 31, 2016. Additions of $21 million recorded. Balance at Dec 31, 2016 was $3 million. Employee count not explicitly disclosed.
2016-12-31restructuringin_progress2016-12-31Southern CaliforniaSouthern California Edison CompanyUSD 21 (millions)restructuring_footnote
f5-10k / Qwen3.6-27B-Q8_0
SCE increased estimated impact for approved workforce reductions during 2016. Severance costs included in operation and maintenance. No specific employee count disclosed.
2016-12-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 21,000,000 (absolute)restructuring_footnote
f5-10k / no-ai-xblr
2016-09-30restructuringin_progress2016-12-31Southern CaliforniaSouthern California Edison CompanyUSD 21 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Ongoing SCE workforce reductions through 2016 to improve productivity and mitigate rate pressure; $21M severance additions for nine months ended 2016-09-30 (balance $9M at period end). No employee count or announcement date disclosed.
2016-09-30restructuringin_progress2016-12-31Southern CaliforniaCorporate / OperationsUSD 21 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE increased estimated impact for approved workforce reductions during the nine months ended Sept 30, 2016. Accrued severance liability balance was $9 million as of Sept 30, 2016, after $21 million in additions and $34 million in payments. Reductions expected to continue through 2016.
2016-09-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 21,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2016-06-30restructuringin_progress2016-12-31Southern CaliforniaSouthern California Edison CompanyUSD 13 (millions)other
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE workforce reductions expected to continue through 2016; severance additions of $13M in 1H 2016, payments of $23M, $12M balance at quarter-end. No employee count disclosed.
2016-06-30othercompletedUnited StatesEdison Energy GroupUSD 13 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
After-tax charge for buy-out of earn-out provision with former shareholders of a company acquired by Edison Energy in 2015, together with employment contract modifications to align long-term incentive compensation. No headcount disclosed.
2016-06-30restructuringin_progress2016-12-31Southern CaliforniaCorporate / OperationsUSD 13 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE increased estimated impact for approved workforce reductions during the six months ended June 30, 2016. Accrued severance liability was $12 million at June 30, 2016. Reductions expected to continue through 2016.
2016-06-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 13,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2016-03-31restructuringin_progress2016-12-31United States (Southern California)Southern California Edison Company — enterprise-wide productivity programUSD 5 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE increased the estimated impact for approved workforce reductions during Q1 2016; program expected to result in further workforce reductions through 2016. Severance liability roll-forward: $22M opening, $5M additions, $15M payments, $12M closing. No employee count disclosed.
2016-03-31restructuringin_progress2016-12-31USD 5 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE increased estimated impact for approved workforce reductions to mitigate rate pressure and optimize cost structure. Accrued severance liability was $12 million at March 31, 2016, after $15 million in payments.
2016-03-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 5,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2015-12-31reduction_in_forcein_progress2016-12-31United States — CaliforniaSouthern California Edison Company (utility operations)USD 26 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Multi-year effort to improve productivity and operational efficiency; 2015 severance accrual additions of $26 million, payments of $39 million, ending accrual $22 million. No employee count for 2015 reductions disclosed; further reductions expected through 2016. Related costs include extended retiree health coverage (special termination benefits).
2015-12-31restructuringin_progress2016-12-31United States (California)Southern California Edison CompanyUSD 26 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
SCE approved workforce reductions during 2015; $26M added to the severance liability, $39M paid, $22M balance at year-end. Number of employees affected is not disclosed. Filer states the program is expected to produce further workforce reductions through 2016.
2015-12-31acquisition_additioncompleted2015-12-312015-12-31United StatesEdison Energy Group (Competitive Businesses)business_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Three businesses acquired for an aggregate purchase price of approximately $100M, expanding energy advisory, engineering/design and renewable sourcing capabilities; headcount added is not disclosed. Up to approximately $50M of contingent consideration may be earned over four years.
2015-12-31restructuringcompleted2015-01-012015-12-31Southern CaliforniaCorporate and OperationalUSD 26 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Higher severance costs related to workforce reduction efforts.
2015-12-31restructuringin_progress2015-01-012016-12-31Southern CaliforniaCorporate and OperationsUSD 26 (millions)restructuring_footnote
f5-10k / Qwen3.6-27B-Q8_0
SCE increased estimated impact for approved workforce reductions during 2015. Severance costs of $26 million recorded in 2015. Program expected to continue through 2016.
2015-12-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 26,000,000 (absolute)restructuring_footnote
f5-10k / no-ai-xblr
2015-09-30restructuringin_progress2016-12-31United StatesSouthern California Edison CompanyUSD 17 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE approved workforce reductions expected through 2016; $17M severance additions in nine months ended 2015; no employee count disclosed
2015-09-30othercompleted2015-09-012015-09-01United StatesSouthern California Edison CompanyMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
2015–2017 collective bargaining agreements with IBEW executed September 1, 2015 covering approximately 3,900 full-time employees; includes pay increases retroactive to January 1, 2015 and modified benefit plans
2015-09-30restructuringin_progress2016-12-31CaliforniaCorporate / OperationsUSD 17 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE continues workforce reductions through 2016 to mitigate rate pressure. $17M in severance additions recorded in the nine months ended Sept 30, 2015. Employee count not disclosed.
2015-09-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 17,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2015-06-30restructuringin_progress2016-12-31United States (Southern California)Southern California Edison CompanyUSD 10 (millions)other
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Ongoing productivity-driven workforce reduction program; filer states further reductions expected through 2016. Severance liability roll-forward: $35M balance at 2015-01-01, $10M additions, $(24)M payments, $21M balance at 2015-06-30. No employee count disclosed. MD&A also cites $10M severance costs in Q2 2015 (same event, deduplicated to footnote).
2015-06-30othercompleted3,9002015-06-30United States (Southern California)Southern California Edison CompanyMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
On 2015-06-30 a majority of IBEW members ratified the Benefits Agreement and Wages and Working Conditions Bargaining Agreement with SCE, covering approximately 3,900 full-time employees; includes pay increases retroactive to 2015-01-01 and modified benefit plans. Prior agreements expired 2014-12-31.
2015-06-30restructuringin_progress2016-12-31Southern CaliforniaCorporate / OperationsUSD 10 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE continues to focus on productivity improvements expected to result in further workforce reductions through 2016. During Q2 2015, SCE increased the estimated impact for workforce reduction approved through the end of the quarter, recording $10 million in severance costs.
2015-06-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 10,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2015-03-31restructuringin_progressUnited StatesSouthern California Edison CompanyUSD 23 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Multi-year workforce reduction program begun 2012, expanded after the 2013 San Onofre retirement decision and 2014 IT outsourcing; $23M of severance paid in Q1 2015 (accrued severance fell from $35M to $12M); cumulative estimated cash severance of $215M through 2015-03-31; no employee count disclosed
2015-03-31otherin_progress3,9002015-01-01United StatesSouthern California Edison Company — IBEW-represented employeesMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
IBEW collective bargaining agreements covering approximately 3,900 full-time employees expired 2014-12-31; expired terms remain in force during negotiations, subject to termination on 120 days written notice; no agreement reached as of filing
2015-03-31restructuringin_progressSouthern CaliforniaCorporate / OperationsUSD 23 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Severance payments related to workforce reductions commenced in 2012 and 2013. Total estimated cash severance through March 31, 2015 is $215 million.
2015-03-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 0 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2014-12-31reduction_in_forcein_progress2012California (SCE service territory)SCE — broad-based cost-reduction effort, including transfer of certain information technology activities to third partiesUSD 4 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Multi-year program commenced in 2012; FY2014 activity included increased estimates for workforce impacts of transferring IT activities to third parties. FY2014 severance expense was $4 million pre-tax ($2 million after-tax), excluding San Onofre-related severance. Severance liability roll-forward for FY2014: $54 million opening, $3 million additions, $22 million payments, $35 million closing. Cumulative estimated cash severance through 2014-12-31 totaled $215 million for all disclosed reductions (includes San Onofre). Filer cautions continued operational-efficiency efforts may lead to additional severance or other charges.
2014-12-31plant_closurecompleted2013-06-06California (San Onofre Nuclear Generating Station)SCE — permanent retirement of San Onofre Units 2 and 3MD&A
f5-10k / GLM-5.3-flash-HTML
SCE decided in June 2013 to permanently retire and decommission San Onofre Units 2 and 3, resulting in additional workforce reductions; affected headcount is not quantified. The severance aspect was resolved in fiscal 2014 when the CPUC approved the San Onofre OII Settlement Agreement (2014-11-20), authorizing rate recovery of recorded 2013 operations and maintenance expense including severance. Decommissioning work is expected to run to roughly 2052, but the workforce reduction action and its severance recovery were completed within the fiscal year.
2014-12-31restructuringin_progressUnited States (Southern California)SCE — enterprise-wide cost-structure optimization, including transfer of certain IT activities to third partiesUSD 4 (millions)other
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Ongoing multi-year workforce reduction program begun 2012; 2014 severance cost of $4M excluding San Onofre-related severance (MD&A), with $3M added to the accrued severance liability during 2014 and $22M of payments. Cumulative estimated cash severance for all such reductions through 2014-12-31 was $215M; accrued severance liability was $35M at year-end. Employees affected not disclosed.
2014-12-31restructuringcompleted2012-01-012014-12-31Southern CaliforniaCorporate and OperationalUSD 2 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
SCE incurred severance costs (after-tax) related to workforce reductions of $2 million in 2014. These reductions commenced in 2012 to optimize cost structure. Estimated cash severance for all workforce reductions totaled $215 million through Dec 31, 2014 (Note 8).
2014-12-31restructuringcompleted2012-01-012014-12-31Southern CaliforniaCorporate and OperationsUSD 2 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
SCE incurred severance costs (after-tax) related to workforce reductions of $2 million in 2014. Part of a broad-based effort commenced in 2012 to reduce costs and improve operational excellence.
2014-12-31restructuringcompleted2013-06-062014-12-31Southern CaliforniaGenerationMD&A
f5-10k / Qwen3.6-27B-Q8_0
Workforce reductions associated with the permanent retirement of San Onofre Units 2 and 3. Severance costs for these specific reductions were recovered in the San Onofre OII Settlement Agreement and excluded from the general workforce reduction costs.
2014-12-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 3,000,000 (absolute)restructuring_footnote
f5-10k / no-ai-xblr
2014-09-30restructuringin_progressUnited States (California)Information Technology / CorporateUSD 45 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE workforce reductions include transferring certain IT activities to third parties. Accrued severance liability was $45M at 2014-09-30 (from $54M at 2014-01-01; $9M additions, $17M payments, $1M other during YTD). Cumulative cash severance through 2014-09-30 totaled $222M. No employee count disclosed.
2014-09-30plant_closurecompleted2013-06-06United States (California)San Onofre Nuclear Generating Station (Units 2 and 3)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE announced permanent retirement of San Onofre Units 2 and 3 on 2013-06-06, resulting in additional workforce reductions. Severance costs related to San Onofre were $1M in YTD 2014 and $79M in YTD 2013. No specific employee count disclosed in this filing.
2014-09-30restructuringin_progress2012-01-01Southern CaliforniaInformation TechnologyUSD 9 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Ongoing workforce reduction efforts commenced in 2012 to optimize cost structure. Q2 2014 saw increased estimated impact for transferring IT activities to third parties. $9M added to severance liability in Q3 2014. Total estimated cash severance through Sept 30, 2014 is $222M.
2014-09-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 9,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2014-06-30restructuringin_progressUnited States (California)Information TechnologyUSD 222 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE workforce reductions tied to outsourcing certain IT activities; estimated cash severance of $222M (SCE share) through June 30, 2014. Severance liability balance was $50M at June 30, 2014. No employee count disclosed.
2014-06-30plant_closurein_progress2013-06-06United States (California)San Onofre Nuclear Generating Station (Units 2 and 3)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Permanent retirement of San Onofre Units 2 and 3 (announced June 2013) resulted in additional workforce reductions; no employee count disclosed in this filing. Severance costs after-tax were $4M in Q2 2014 and $5M YTD 2014.
2014-06-30restructuringin_progress2012-01-01CaliforniaInformation TechnologyUSD 9 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE increased estimated impact for workforce reductions related to transferring certain IT activities to third parties. Additions of $9 million recorded in Q2 2014. Total estimated cash severance through June 30, 2014 is $222 million.
2014-06-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 9,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2014-03-31restructuringin_progress2012-01-01Southern California, United StatesSouthern California Edison Company (utility operations)USD 213 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE began multiple workforce reduction efforts in 2012 to optimize cost structure; additional reductions followed the June 2013 decision to retire San Onofre. Cumulative cash severance through 2014-03-31 totaled $213M. Accrued severance liability was $44M at quarter-end after $10M in payments during Q1 2014. No employee count disclosed.
2014-03-31restructuringin_progress2012-01-01Southern CaliforniaCorporate and OperationsUSD 213 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE commenced multiple efforts in 2012 to reduce workforce to optimize cost structure. In June 2013, announced plans to permanently retire San Onofre, resulting in additional reductions. Through March 31, 2014, SCE's share of estimated cash severance totaled $213 million. Accrued liability was $44 million at quarter-end.
2014-03-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 0 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2013-12-31plant_closurein_progress9602013-06-06California (San Onofre Nuclear Generating Station)SCE — nuclear generation (San Onofre Units 2 and 3)USD 39 (millions)other
f5-10k / GLM-5.3-flash-HTML
Workforce reduction of approximately 960 employees announced with the June 6, 2013 decision to permanently retire Units 2 and 3; $39 million is SCE's share of 2013 severance costs previously included in the decommissioning estimate. An additional $14 million of severance was recorded for indirect employee impacts from the early retirement decision. No completion date disclosed.
2013-12-31reduction_in_forceannounced1752013-06-06California (San Onofre Nuclear Generating Station)SCE — nuclear generation (San Onofre)other
f5-10k / GLM-5.3-flash-HTML
Further reduction of approximately 175 employees expected after NRC acceptance of the decommissioning plan; timing contingent on that acceptance and not specified. Treated as a sub-component of the June 2013 San Onofre retirement program.
2013-12-31restructuringin_progress2012California (SCE service area)SCE utility-wide cost structure optimizationrestructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Multiple workforce-reduction efforts commenced in 2012 to optimize cost structure and continued through 2013; headcount for this program not separately disclosed. Combined across all efforts (including San Onofre), SCE's share of estimated cash severance totaled $213 million through December 31, 2013 (cumulative); 2013 accrued severance roll-forward: $104 million opening, $101 million additions, $151 million payments, $54 million year-end balance.
2013-12-31restructuringin_progress9602013-06-06United States (California)San Onofre nuclear plantUSD 39 (millions)other
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Workforce reduction announced with the June 6, 2013 decision to permanently retire San Onofre Units 2 and 3; severance cost is SCE's share recorded in 2013. A further $14 million of severance was recorded for indirect employee impacts of the early-retirement decision. SCE expects an additional reduction of about 175 employees after NRC acceptance of the decommissioning plan.
2013-12-31restructuringin_progress2012-01-01United States (California)Southern California Edison Companyother
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Multi-year SCE workforce reduction efforts begun in 2012 continued into 2013; no employee count is disclosed. Severance liability roll-forward for 2013: opening balance $104 million, additions $101 million, payments $151 million, closing balance $54 million; cumulative estimated cash severance of $213 million through December 31, 2013.
2013-12-31acquisition_additioncompleted2013-08-01United StatesCompetitive Businesses — distributed solar developmentItem_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Edison International acquired SoCore Energy, LLC in August 2013 (commercial rooftop distributed solar developer); no headcount added is disclosed. Month only is stated, so date is approximate.
2013-12-31restructuringcompleted9602013-06-06CaliforniaSan Onofre Nuclear Generating StationUSD 39 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Workforce reduction announced in June 2013 following decision to permanently retire San Onofre Units 2 and 3. Severance costs of $39 million recorded in 2013.
2013-12-31restructuringcompleted2013-06-06CaliforniaCorporate/IndirectUSD 14 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Severance costs of $14 million related to indirect employee impacts from the decision to early retire San Onofre Units.
2013-12-31restructuringcompleted9602013-06-06CaliforniaSan Onofre Nuclear Generating StationUSD 39 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Workforce reduction announced upon decision to permanently retire San Onofre Units 2 and 3. $39 million in severance costs recorded in 2013.
2013-12-31restructuringcompleted2013-06-06CaliforniaCorporate / IndirectUSD 14 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Severance costs related to indirect employee impacts from the decision to early retire San Onofre Units.
2013-12-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 101,000,000 (absolute)restructuring_footnote
f5-10k / no-ai-xblr
2013-09-30restructuringcompleted2013-06-30United States — Southern CaliforniaSouthern California Edison Company — enterprise-widerestructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE began multiple workforce reduction efforts in 2012 to optimize cost structure; largely completed by end of Q2 2013. No affected-employee count disclosed. Accrued severance liability roll-forward for 2013: $104M opening, $109M additions, $132M payments, $81M at 2013-09-30.
2013-09-30plant_closurein_progress9602013-06-06United States — Southern California (San Onofre)San Onofre Nuclear Generating Station workforceUSD 56 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Follows the 2013-06-06 decision to permanently retire San Onofre Units 2 and 3; majority of reductions occurred in 2013. $56M severance accrued (SCE's share), probable of recovery in future rates; a further $14M severance recorded for indirect employee impacts.
2013-09-30reduction_in_forceannounced1752013-06-06United States — Southern California (San Onofre)Support organizationsrestructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Further reduction expected after NRC acceptance of the San Onofre decommissioning plan; timing not specified. Related to the same San Onofre retirement decision as the 960-employee reduction.
2013-09-30restructuringin_progress9602013-06-06San OnofreSan Onofre workforceUSD 56 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Workforce reduction associated with permanent retirement of San Onofre Units 2 and 3. Accrued additional severance costs of $56 million.
2013-09-30restructuringin_progress1752013-06-06San OnofreSupport organizationsrestructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Further reduction of support organizations expected after acceptance of decommissioning plan by NRC.
2013-09-30restructuringin_progress2013-06-06San OnofreIndirect employee impactsUSD 14 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Severance costs related to indirect employee impacts from the decision to early retire the Units.
2013-09-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 109,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2013-09-30restructuringin_progress960Southern California Edison Company [Member] / San Onofre [Member]restructuring_footnote
f5-10q / no-ai-xblr
Expected positions to be eliminated
2013-06-30plant_closurein_progress9602013-06-062013-12-31California (San Onofre site)San Onofre nuclear plant workforceUSD 56 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Follows June 6, 2013 decision to permanently retire San Onofre Units 2 and 3; majority of reductions expected in 2013. Severance is SCE's share; $32M of the cost deferred as a regulatory asset and $24M offset by authorized revenue, so no earnings impact.
2013-06-30restructuringannounced1752013-06-06CaliforniaSupport organizations / decommissioning workforcerestructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Support-organization reduction announced with the San Onofre retirement; a further reduction of approximately 175 employees is expected after NRC acceptance of the decommissioning plan. Timing not specified.
2013-06-30restructuringin_progress2013-06-30CaliforniaSouthern California Edison Company (enterprise-wide)USD 109 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Multi-year cost-structure workforce reduction program begun in 2012, largely completed by end of Q2 2013; no employee count disclosed. Severance additions of $109M and payments of $88M in the six months ended June 30, 2013; liability balance $125M at quarter-end. $61M of severance accrued in Q2 2013, of which $37M impacted earnings.
2013-06-30restructuringin_progress2013-06-06CaliforniaIndirect / corporate employees affected by San Onofre retirementUSD 14 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Severance for indirect employee impacts of the early retirement decision; no regulatory asset recorded because these employees sit in SCE base rates. Headcount not disclosed.
2013-06-30restructuringin_progress9602013-06-062013-12-31CaliforniaSan Onofre Nuclear Generating StationUSD 56 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Workforce reduction associated with permanent retirement of San Onofre Units 2 and 3. Majority of reductions expected in 2013.
2013-06-30restructuringin_progress1752013-06-06CaliforniaSan Onofre Support Organizationsrestructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Support organization reductions associated with San Onofre retirement. Expected to occur after NRC acceptance of decommissioning plan.
2013-06-30restructuringin_progress2013-06-06CaliforniaIndirect Employee ImpactsUSD 14 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Severance costs related to indirect employee impacts from early retirement decision. Employees included in base rates.
2013-06-30restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 109,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2013-06-30restructuringin_progress175Southern California Edison Company [Member] / San Onofre [Member] / Decommissioning Plan [Member]restructuring_footnote
f5-10q / no-ai-xblr
Expected positions to be eliminated
2013-06-30restructuringin_progress960Southern California Edison Company [Member] / San Onofre [Member]restructuring_footnote
f5-10q / no-ai-xblr
Expected positions to be eliminated
2013-03-31restructuringin_progressUnited States (Southern California)Southern California Edison Company — workforce reduction effortsUSD 16 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE began multiple workforce reduction efforts in 2012 to optimize its cost structure and align with peers. Severance liability roll-forward: $104M at Jan 1, 2013; $16M additions and $61M payments during Q1 2013; $59M at Mar 31, 2013. No employee count disclosed. MD&A notes $16M of accrued severance costs in Q1 2013 O&M expense.
2013-03-31restructuringin_progress2012-01-01Southern CaliforniaCorporate / GeneralUSD 16 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
SCE commenced multiple efforts in 2012 to reduce its workforce to optimize cost structure. Additions to accrued severance liability were $16 million for the three months ended March 31, 2013. Payments were $61 million. Ending liability was $59 million. Employee count affected not disclosed.
2013-03-31restructuringin_progressSouthern California Edison Company [Member] / Employee Severance [Member]USD 16,000,000 (absolute)restructuring_footnote
f5-10q / no-ai-xblr
2012-12-31restructuringin_progress20122013California, United StatesSan Onofre Nuclear Generating Station (SONGS)USD 36 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Downsizing of the San Onofre organization announced in 2012 to align its cost structure with industry peers; the $36 million is SCE's estimated share of cash severance recorded at December 31, 2012. MD&A ties these reductions to plans in the 2012 GRC. Reductions began in the fourth quarter of 2012 and continue into 2013; severance payments expected complete in 2013. No affected-employee count disclosed.
2012-12-31restructuringin_progress20122013California, United StatesCompany-wide (SCE)USD 76 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Separate reorganization event under which SCE implemented plans to reduce its workforce; $76 million of estimated severance recorded at December 31, 2012. Reductions began in the fourth quarter of 2012 and continue into 2013, with severance payments expected complete in 2013. Together with the San Onofre action, MD&A cites $112 million of 2012 severance costs. No affected-employee count disclosed.
2012-12-31otherin_progress2012-12-172014-12-31Edison Mission Group / Edison Mission Energy (nonutility competitive power generation)discontinued_operations_footnote
f5-10k / GLM-5.3-flash-HTML
EME and certain subsidiaries filed voluntary Chapter 11 petitions on the Petition Date; Edison International deconsolidated EME effective that date, removing EME's workforce from the consolidated group (results reported as discontinued operations). Under the Support Agreement, Edison International plans to transfer EME stock to unsecured creditors no later than December 31, 2014 and will assume certain EME employee retirement liabilities (an $80 million joint qualified retirement plan liability was recorded). No EME employee headcount is disclosed in this filing.
2012-12-31restructuringin_progress2012-01-012013-12-31United States — Southern CaliforniaSan Onofre organizationUSD 36 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Estimated cash severance (SCE's share) for the San Onofre workforce reduction announced in 2012 to align the plant's cost structure with industry peers; headcount not disclosed. Reductions began in Q4 2012 and are expected to complete during 2013. Announcement date shown as fiscal-year start because no specific date is given.
2012-12-31restructuringin_progress2012-01-012013-12-31United States — Southern CaliforniaSCE — general reorganizationUSD 76 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Estimated severance recorded for a separate 2012 reorganization event; headcount not disclosed. Reductions began in Q4 2012 and are expected to complete during 2013. Announcement date shown as fiscal-year start because no specific date is given.
2012-12-31restructuringin_progress20122013Southern CaliforniaSan Onofre Nuclear Generating StationUSD 112 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
SCE announced plans for downsizing to bring San Onofre organization and cost structure in line with industry peers. $112 million in severance costs recorded in 2012. Payments expected to be completed in 2013. Employee count not explicitly disclosed.
2012-12-31restructuringin_progress2012-01-012013-12-31Southern CaliforniaSan Onofre / General WorkforceUSD 112 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
SCE incurred $112 million in severance costs related to employee reductions at San Onofre and approved reductions for 2013 to optimize cost structure. Reductions began in Q4 2012 and are expected to complete in 2013.
2012-09-30restructuringannounced7302012-08-012013-12-31United States (San Clemente/San Diego, California)Southern California Edison — San Onofre nuclear plant workforceUSD 30 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE plans to reduce the San Onofre workforce by 730 employees to 1,500 employees, beginning Q4 2012 and continuing through 2013. $30 million estimated cash severance cost (SCE's share) for non-represented employees recorded at 2012-09-30. Announcement month stated as August 2012; day not specified.
2012-09-30restructuringannounced7302012-08-012013-12-31Southern CaliforniaSan Onofre Nuclear Generating StationUSD 30 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE announced plans to reduce the San Onofre workforce by 730 employees to 1,500 employees beginning in Q4 2012 and continuing in 2013. Recorded $30 million in estimated cash severance costs for non-represented employees.
2012-03-31plant_closureannounced2012-03-312012-09-30United States (Illinois)EMG — Midwest Generation (Fisk and Crawford Stations)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EMG decided to shut down Fisk and Crawford Stations in September 2012; PJM approved. Estimated 150 to 180 employees affected. Severance benefits not required under existing collective bargaining agreement; timing and amount of any severance to be determined after personnel review based on seniority.
2012-03-31restructuringannounced1652012-03-312012-09-30IllinoisMidwest GenerationMD&A
f5-10q / Qwen3.6-27B-Q8_0
Shutdown of Fisk and Crawford Stations in September 2012; 150 to 180 employees affected. Timing and amount of severance benefits to be determined after review.
2011-12-31plant_closureannounced1502012-02Illinois, United StatesMidwest Generation (EMG competitive power generation segment)subsequent_events
f5-10k / GLM-5.3-flash-HTML
Decision made in February 2012, after the fiscal year-end. Fisk Station to shut by end of 2012 and Crawford Station by end of 2014, subject to PJM reliability review, so no single completion date applies. Headcount disclosed only as an aggregate range of 150 to 180 across both stations; the lower bound is recorded. EMG recorded a $640 million impairment charge at December 31, 2011 across the Crawford, Fisk and Waukegan Stations (Note 16: $115M Fisk, $186M Crawford, $339M Waukegan); the charge includes Waukegan, which is not slated for closure. Severance amounts, if any, to be determined after a personnel review. EME indicated it may ultimately shut the Waukegan Station and Joliet Unit 6 rather than install controls, but no shutdown decision had been made.
2011-12-31restructuringcompletedRenewable energy development (EMG)USD 34 (millions)MD&A
f5-10k / GLM-5.3-flash-HTML
During the fourth quarter of 2011, EMG scaled back renewable development to conserve cash, cutting staffing and joint-development funding and shrinking the wind development pipeline to roughly 1,300 MW. Charges of $34 million were triggered; the composition (e.g., severance versus write-offs of capitalized development costs) is not specified. The headcount reduction is not quantified.
2011-12-31plant_closureannounced2012-02-292014-12-31Illinois, United StatesEdison Mission Group — Midwest Generation coal plantsUSD 640 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
In February 2012 Midwest Generation decided to shut Fisk Station by end of 2012 and Crawford Station by end of 2014; $640M impairment covers Crawford, Fisk and Waukegan Stations. Filer estimates 150 to 180 employees affected in total across the closures.
2011-12-31plant_closureannounced2012-02-292012-12-31Illinois, United StatesEdison Mission Group — Midwest Generation, Fisk StationUSD 115 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Impairment charge of $115 million for Fisk Station; closure decision made in February 2012 (subsequent to fiscal year-end).
2011-12-31plant_closureannounced2012-02-292014-12-31Illinois, United StatesEdison Mission Group — Midwest Generation, Crawford StationUSD 186 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Impairment charge of $186 million for Crawford Station; closure decision made in February 2012 (subsequent to fiscal year-end).
2011-12-31plant_closureannounced2012-02-29Illinois, United StatesEdison Mission Group — Midwest Generation, Waukegan StationUSD 339 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Filer concluded it less likely to retrofit Waukegan Station; $339 million impairment. No closure date or headcount disclosed.
2011-12-31restructuringcompleted1802012-02-012014-12-31IllinoisEdison Mission Group (Midwest Generation)USD 640 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Decision to shut down Fisk Station by end of 2012 and Crawford Station by end of 2014. 150-180 employees affected. Impairment charge of $640 million recorded in Q4 2011.
2011-12-31restructuringcompleted2011-12-31United StatesEdison Mission Group (Renewable Energy)USD 34 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Significant reduction in development of renewable energy projects to conserve cash. Staffing reduced and joint development funding reduced. Charge of $34 million recorded in Q4 2011.
2011-12-31restructuringcompleted2011-12-312011-12-31United StatesEdison Mission Group (EMG)USD 34 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
EMG reduced staffing and development pipeline for wind projects. Specific headcount not disclosed, only charge amount.
2011-12-31plant_closureannounced2012-02-012012-12-31IllinoisMidwest Generation (EMG)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Midwest Generation decided to shut down Fisk Station by end of 2012. 150-180 employees affected by Fisk and Crawford closures combined, but specific count for Fisk not isolated.
2011-12-31plant_closureannounced2012-02-012014-12-31IllinoisMidwest Generation (EMG)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Midwest Generation decided to shut down Crawford Station by end of 2014. 150-180 employees affected by Fisk and Crawford closures combined, but specific count for Crawford not isolated.
2010-12-31restructuringcompleted752009-042009-04United StatesEdison Mission Group (EMG)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Reduction of approximately 75 positions in regional and corporate offices in April 2009.
2010-12-31restructuringcompleted752009-042009-04United StatesEMG (Edison Mission Group)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Reduction of approximately 75 positions in regional and corporate offices in April 2009.
2009-09-30restructuringcompleted752009-04-01United StatesCompetitive Power Generation (EME) — regional and corporate officesMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Action occurred in April 2009 (Q2) but is disclosed in this Q3 filing as context for lower administrative expenses; no severance charge quantified.
2009-09-30restructuringcompleted752009-04-01United StatesRegional and Corporate OfficesMD&A
f5-10q / Qwen3.6-27B-Q8_0
EME reduced approximately 75 positions in its regional and corporate offices in April 2009. Year-to-date decrease in expenses partially offset by restructuring expenses.
2009-03-31restructuringannounced752009-04-01United StatesEdison Mission Group (EME) — regional and corporate officesUSD 6 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Post-quarter action; charge expected in Q2 2009. Filer states approximately 75 positions reduced.
2009-03-31restructuringannounced752009-04-012009-06-30United StatesCorporate and Regional OfficesUSD 6 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
EME reduced approximately 75 positions in regional and corporate offices; restructuring charge of approximately $6 million expected in Q2 2009.
2008-06-30othercompleted2008-06-30CaliforniaTransmission and DistributionMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE disciplined and/or terminated certain employees, including several supervisory personnel, following an internal investigation into misconduct regarding customer satisfaction surveys and employee injury/illness reporting.
2008-03-31othercompletedCaliforniaTransmission and DistributionMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE disciplined and/or terminated certain employees, including supervisory personnel, following internal investigations into misconduct regarding customer satisfaction surveys and employee injury reporting.
2007-12-31plant_closurecompleted2006-06-192007-12-31Arizona, United States (Navajo Nation lands)SCE — Mohave Generating StationUSD 5 (millions)MD&A
f5-10k / GLM-5.3-flash-HTML
Multi-year wind-down: Mohave suspended operations 2005-12-31; SCE announced on 2006-06-19 it would not pursue returning the plant to service. Workforce was reduced from over 300 employees to 37 by year-end 2007 (exact number of employees affected not stated, so not derived). SCE recorded $5 million of termination costs in 2007 (SCE's share), deferred in a balancing account under the 2006 GRC decision; pension-note disclosures also attribute special termination benefits to the Mohave shutdown.
2007-12-31restructuringcompleted2632005-12-312007-12-31NevadaSouthern California Edison Company (SCE)USD 5 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Mohave plant ceased operations on Dec 31, 2005. Workforce reduced from over 300 to 37 by end of 2007. SCE recorded $5 million in termination costs during 2007.
2007-12-31restructuringcompleted2632005-12-312007-12-31ArizonaSouthern California Edison Company (SCE)USD 5 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Workforce reduced from over 300 employees to 37 employees by end of 2007 following Mohave plant shutdown. SCE recorded $5 million in termination costs during 2007.
2007-03-31otherin_progress2007-03-31CaliforniaTransmission and Distributionother
f5-10q / Qwen3.6-27B-Q8_0
SCE disciplined and/or terminated certain employees, including supervisory personnel, following an internal investigation into misconduct regarding customer satisfaction surveys and employee injury reporting.
2006-12-31plant_closurecompleted2005-12-312006-12-31Clark County, Nevada (Mohave Generating Station, co-owned by SCE)SCE — electric utility generationUSD 15 (millions)other
f5-10k / GLM-5.3-flash-HTML
Mohave ceased operations December 31, 2005 per a 1999 consent decree; workforce reduced from over 300 employees to approximately 65 by end of 2006. SCE announced on June 19, 2006 that it would not pursue returning the plant to service. The $15 million termination costs (SCE's share) were recorded during 2006, deferred in a balancing account authorized in the 2006 GRC decision, and are expected to be recovered in future rate-making proceedings. Related special termination benefit costs also appear in the pension and PBOP expense for 2006.
2006-12-31plant_closurecompleted2006-06-192006-12-31United States (Clark County, Nevada, near the California border)SCE — Mohave Generating StationUSD 15 (millions)MD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Plant ceased operations 2005-12-31; SCE announced on 2006-06-19 it would not pursue return to service. Workforce reduced from over 300 employees to approximately 65 by year-end 2006 (filer does not state an explicit reduction count). $15 million of termination costs (SCE's share) recorded during 2006 and deferred in an authorized balancing account.
2006-12-31restructuringcompleted2352005-12-312006-12-31NevadaSouthern California Edison Company (SCE)USD 15 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Workforce reduced from over 300 employees to 65 employees by end of 2006 following suspension of Mohave operations on Dec 31, 2005. SCE recorded $15 million in termination costs.
2006-12-31restructuringcompleted2352005-12-312006-12-31ArizonaSouthern California Edison Company (SCE)USD 15 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
Workforce reduced from over 300 employees to 65 employees by end of 2006 following Mohave plant shutdown. SCE recorded $15 million in termination costs.
2006-09-30plant_closurein_progress2006-06-192006-12-31United States (California/Arizona)Electric Utility (SCE) — Mohave Generating StationUSD 16 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Workforce to shrink from over 300 to about 65 by end-2006; $7M termination costs in Q2 and $9M in Q3 (SCE's share), deferred to a CPUC-authorized balancing account.
2006-09-30otherin_progressUnited StatesElectric Utility (SCE)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Special termination benefits incurred in pension and OPEB plans due to the Mohave shutdown; no employee count disclosed.
2006-09-30restructuringin_progress2352006-06-192006-12-31CaliforniaElectric Utility (SCE)USD 16 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Workforce reduction at Mohave Generating Station from over 300 to approx. 65 employees by end of 2006. Total termination costs recorded: $7M in Q2 and $9M in Q3 (SCE's share).
2006-06-30plant_closurecompleted2006-04-012006-06-30United States (Arizona/California)Electric utility — Mohave Generating StationUSD 7 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Workforce cut from over 300 to about 224 after the plant ceased operations Dec 31, 2005; impacted employees notified April 2006, reduction completed June 30, 2006. Termination costs deferred in a balancing account authorized in the 2006 GRC decision. Filer does not state an explicit number of employees separated.
2006-06-30layoffannounced2006-07-012006-12-31United States (Arizona/California)Electric utility — Mohave Generating Stationother
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Co-owners decided in July 2006 to further reduce the Mohave workforce to 65 employees before end of 2006. Filer states termination costs and other cessation costs (excluding decommissioning) will range from zero to $14 million (SCE's share), recorded and deferred in the Mohave balancing account in late 2006; exact separation count not disclosed.
2006-06-30restructuringcompleted762006-04-012006-06-30ArizonaElectric Utility (SCE) - Mohave Generating StationUSD 7 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Workforce reduced from over 300 to approx. 224 employees. Impacted employees notified in April 2006; reduction completed by June 30, 2006. Termination costs of approx. $7 million (SCE's share) recorded in Q2.
2006-06-30restructuringannounced1592006-07-012006-12-31ArizonaElectric Utility (SCE) - Mohave Generating Stationsubsequent_events
f5-10q / Qwen3.6-27B-Q8_0
Co-owners decided in July 2006 to further reduce workforce to 65 employees before end of 2006. Reduction of approx. 159 employees (224 current - 65 target). Costs uncertain and not yet recorded.
2006-03-31othercompleted2006-03-31CaliforniaTransmission and DistributionMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE severed employment of several supervisory personnel following investigation into customer satisfaction survey misconduct.
2005-12-31restructuringcompleted2005-12-262005-12-26Irvine, California, United StatesEdison Capital; management and administrative functionsItem_1_Business
f5-10k / GLM-5.3-flash-HTML
Internal reorganization: during 2005 EME streamlined reporting relationships, eliminated its regional management structure, and combined Irvine, California management teams with Edison Capital; all existing Edison Capital employees were transferred to EME under a services agreement effective December 26, 2005 (date fields reflect that effective date). Intercompany transfer with no consolidated headcount reduction disclosed; Edison Capital reported 41 full-time employees in 2005 selected operating data.
2005-12-31plant_closurecompleted2005-12-312005-12-31Clark County, Nevada, United StatesSCE — Mohave Generating Station (coal-fired generation)MD&A
f5-10k / GLM-5.3-flash-HTML
SCE's 56%-owned, 885 MW (net) coal plant ceased operation December 31, 2005 as scheduled under a 1999 consent decree after agreements with the Navajo Nation and Hopi Tribe on post-2005 coal and water supply were not reached; shutdown is indefinite with a possible restart and no definite return-to-service date. No employee-impact figure is disclosed; date fields reflect the cessation date rather than a new announcement.
2005-12-31plant_closurecompleted2005-12-312005-12-31Clark County, Nevada (SCE service area)SCE — Mohave Generating Station coal generationItem_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Shutdown driven by unresolved post-2005 coal and water supply agreements with the Navajo Nation and Hopi Tribe and the 1999 consent decree; no definite return-to-service date. Employees affected not disclosed.
2005-12-31restructuringcompleted2005-01-012005-12-31United StatesEME — management and organizationItem_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Streamlined reporting relationships and eliminated EME's regional management structure; combined Irvine management teams of EME and Edison Capital. Positions eliminated not disclosed.
2005-12-31divestiture_reductioncompleted2005-01-102005-01-10PhilippinesEME — discontinued operations (CBK hydroelectric project)discontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Part of EME's 2004-early 2005 sale of international assets totaling 6,452 MW. Employees affected not disclosed.
2005-12-31divestiture_reductioncompleted2005-02-032005-02-03ThailandEME — discontinued operations (Tri Energy project)discontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Sold to IPM consortium for approximately $20 million. Employees affected not disclosed.
2005-09-30restructuringin_progressEdison Mission Energy (EME)USD 10 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Management and organizational changes to streamline reporting relationships and eliminate regional management structure. Charge recorded for severance and related costs in the nine months ended Sept 30, 2005.
2005-09-30othercompleted242005-06-01Southern California Edison (SCE)Notes to Consolidated Financial Statements
f5-10q / Qwen3.6-27B-Q8_0
Disciplinary action taken against twenty-four individuals in several SCE business areas in early June 2005 related to employee injury and illness reporting inaccuracies.
2005-09-30othercompletedSouthern California Edison (SCE)Notes to Consolidated Financial Statements
f5-10q / Qwen3.6-27B-Q8_0
Severing of employment of several supervisory personnel in the design organization of the transmission and distribution business unit due to deliberate alteration of customer contact information.
2005-06-30restructuringin_progressUnited StatesNonutility power generation (EME) — domestic organizationUSD 10 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME streamlined reporting relationships and eliminated its regional management structure; charges of $3M (Q2) and $10M (YTD) pre-tax for severance and related costs. Expected annualized pre-tax cost reduction of $7M, partly offset by higher development costs. No employee count disclosed.
2005-06-30restructuringin_progress2005-06-30United StatesEdison Mission Energy (EME)USD 3 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
EME recorded charges of approximately $3 million (pre-tax) in the quarter ended June 30, 2005, for severance and related costs as part of a review of its domestic organization to streamline reporting relationships and eliminate regional management structure. Employee count not disclosed.
2005-06-30restructuringin_progress2005-06-30United StatesEdison Mission Energy (EME)USD 10 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
EME recorded charges of approximately $10 million (pre-tax) in the six months ended June 30, 2005, for severance and related costs. Employee count not disclosed.
2005-06-30othercompleted242005-06-012005-06-30CaliforniaSouthern California Edison (SCE)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE took disciplinary action against twenty-four individuals in several SCE business areas in early June 2005 related to employee injury and illness reporting inaccuracies.
2005-03-31restructuringin_progress2005-06-30United StatesNonutility power generation (EME) — corporate and regional managementUSD 7 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Pre-tax severance charge recorded in Q1 2005 for domestic organization streamlining; an additional $4 million pre-tax charge expected in Q2 2005. No employee count disclosed. Expected annualized cost savings of $7 million pre-tax.
2005-03-31restructuringannounced2005-06-30United StatesNonutility power generation (EME) — corporate and regional managementUSD 4 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Additional pre-tax charge expected in Q2 2005 for restructuring steps completed after March 31, 2005. No employee count disclosed.
2005-03-31othercompletedUnited StatesSouthern California Edison — transmission and distribution design organizationother
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE severed employment of several supervisory personnel following customer-satisfaction survey misconduct investigation; no count disclosed. Approximately 20 employees disciplined for misconduct were interviewed by CPUC's Consumer Protection and Safety Division.
2005-03-31restructuringin_progress2005-03-31Edison Mission Energy (EME)USD 7 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
EME recorded a $7 million pre-tax charge for severance and related costs associated with organizational changes to streamline reporting relationships and eliminate regional management structure. An additional $4 million charge is expected in Q2 2005.
2005-03-31othercompleted362004-06-25Southern CaliforniaSouthern California Edison (SCE) - Transmission and DistributionMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE severed employment of several supervisory personnel and disciplined approximately 20 employees following investigation into customer satisfaction survey misconduct. 36 design organization personnel engaged in deliberate misconduct.
2004-12-31plant_closurecompleted2004-05-282004-12-31Morris, Illinois, United StatesMidwest Generation, LLC (EME) — coal-fired generation (Collins Station)USD 956 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
Lease terminated April 27, 2004 via ~$960 million termination payment; Note 14 reports a pre-tax loss of ~$956 million (~$587 million after tax) covering lease termination, decommissioning and excess inventory, while MD&A passages cite $951–$961 million. All units permanently retired and decommissioned by Q4 2004, permits surrendered; headcount impact not separately quantified. A separate $5 million pre-tax impairment in September 2004 arose from terminating the power purchase agreement for the two units still under contract.
2004-12-31reduction_in_forcecompletedIllinois, United StatesEME / Midwest Generation — Illinois plantsUSD 4 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
$4 million pre-tax exit-cost charge recorded in other operation and maintenance expense for reducing the workforce in Illinois during Q4 2004; number of employees affected not disclosed. Contextually associated with the Collins Station decommissioning.
2004-12-31plant_closureannounced2004-09-30Illinois, United StatesEME / Midwest Generation — small peaking unitsUSD 29 (millions)restructuring_footnote
f5-10k / GLM-5.3-flash-HTML
After a September 2004 competitiveness analysis in the expanded PJM market, planning began to decommission six of eight small peaking units; $29 million pre-tax asset impairment (~$18 million after tax) recorded in Q3 2004. Workforce impact not quantified.
2004-12-31divestiture_reductioncompletedInternational — New Zealand, Australia, Europe, Asia, Puerto Rico, Philippines, Thailand, TurkeyMEHC / EME — international power generation portfoliodiscontinued_operations_footnote
f5-10k / GLM-5.3-flash-HTML
Sales under EME's restructuring plan announced in Q4 2003: Contact Energy (completed September 30, 2004), MEC International B.V. with ten projects (completed December 16, 2004), CBK (completed January 10, 2005) and Tri Energy (completed February 3, 2005). No transferred-employee counts disclosed. MEHC full-time employees declined from 2,610 at year-end 2003 to 1,768 at year-end 2004 per the Selected Financial and Operating Data table, coinciding with these divestitures.
2004-12-31acquisition_additioncompleted2004-03-12Redlands, California, United StatesSCE — generation (Mountainview project)USD 285 (millions)business_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
SCE acquired Mountainview Power Company LLC, owner of a power plant under construction (~$600 million project, expected completion early 2006); $285 million of acquisition costs disclosed. Headcount added through the acquisition was not disclosed.
2004-12-31plant_closurecompleted2004-05-282004-12-31Illinois, United StatesNonutility power generation — Midwest Generation (EME)USD 961 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Collins Station lease terminated April 27, 2004; plant permanently ceased operations, was decommissioned and all units retired by Q4 2004. Charge is lease termination loss and asset impairment, not severance; no employee count disclosed.
2004-12-31restructuringcompleted2004-12-31Illinois, United StatesNonutility power generation — Midwest Generation (EME)USD 4 (millions)restructuring_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Exit costs recorded in Q4 2004 for reducing the workforce in Illinois; number of employees affected not disclosed. Related $5 million pre-tax charge recorded September 2004 on termination of the Collins Station power purchase agreement.
2004-12-31divestiture_reductioncompleted2005-02-03International (Europe, Asia, Australia, New Zealand, Philippines, Puerto Rico)Nonutility power generation — Edison Mission Energy (EME)discontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Sale of substantially all EME international assets (6,452 MW): Contact Energy completed 2004-09-30, MEC International B.V. (ten projects) completed 2004-12-16, CBK completed 2005-01-10, Tri Energy completed 2005-02-03. Headcount removed through these dispositions is not disclosed.
2004-12-31othercompletedCalifornia, United StatesElectric utility — Southern California Edison Company (SCE)USD 29 (millions)MD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
SCE terminated and disciplined certain employees after finding falsified customer-safety data used for CPUC performance incentives; number terminated not disclosed. $29 million pre-tax charge accrued in 2004 for anticipated refund of previously received incentive rewards.
2004-09-30restructuringannounced2004-10Illinois, United StatesNonutility power generation (EME / Midwest Generation)USD 4 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME finalized plans in October 2004 to reduce the Illinois workforce; pre-tax exit-cost charge expected in Q4 2004. Headcount not disclosed.
2004-09-30plant_closurein_progress2004-04-272004-12-31Illinois, United StatesNonutility power generation (Midwest Generation — Collins Station)USD 956 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Collins Station lease terminated April 27, 2004; plant to permanently cease operations and be decommissioned by December 31, 2004. Employee count not disclosed.
2004-09-30plant_closurein_progress2004-09Illinois, United StatesNonutility power generation (Midwest Generation — six of eight small peaking units)USD 29 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Decision in September 2004 to decommission six of eight Illinois peaking units, subject to regulatory approval; pre-tax impairment charge recorded. Employee count not disclosed.
2004-09-30restructuringcompleted2004-04-272004-12-31IllinoisNonutility Power GenerationUSD 956 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Termination of Collins Station lease and planned decommissioning. Pre-tax loss of approx $956M recorded in Q2 2004. Operations ceased by Dec 31, 2004.
2004-09-30restructuringcompleted2004-09-302004-09-30IllinoisNonutility Power GenerationUSD 5 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Impairment charge related to termination of power purchase agreement for Collins Station units.
2004-09-30restructuringcompleted2004-09-302004-09-30IllinoisNonutility Power GenerationUSD 29 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Impairment charge for six of eight small peaking units in Illinois due to decommissioning decision.
2004-09-30restructuringannounced2004-10-012004-12-31IllinoisNonutility Power GenerationUSD 4 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Workforce reduction in Illinois finalized in Oct 2004. Expected to recognize $4M pre-tax charge for exit costs in Q4 2004.
2004-06-30plant_closurein_progress2004-04-272004-12-31United States (Illinois)Nonutility power generation (Midwest Generation)USD 954 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Collins Station lease terminated; plant to cease operations and be decommissioned by year-end 2004. Filer states exit costs for expected personnel reductions were not accrued because amounts were not determinable at June 30, 2004; no employee count disclosed. Charge is pre-tax loss on lease termination (~$586 million after tax).
2004-06-30reduction_in_forcecompleted2004-06-25United States (California)Electric utility (SCE) — transmission and distribution supervisory personnelother
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Disciplinary terminations following an internal investigation into manipulated customer-satisfaction survey data; filer says several supervisory personnel were severed but gives no count. Related proposed refunds of up to $14 million in performance-based ratemaking rewards are not workforce charges.
2004-06-30restructuringin_progress2004-04-272004-12-31IllinoisNonutility Power GenerationUSD 954 (millions)restructuring_footnote
f5-10q / Qwen3.6-27B-Q8_0
Termination of Collins Station lease and planned decommissioning. Pre-tax loss of $954 million recorded. Operations to cease by Dec 31, 2004. Exit costs for personnel reduction not determinable at June 30, 2004.
2004-06-30othercompleted362004-06-252004-06-25CaliforniaElectric Utility (SCE)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Severance of several supervisory personnel following investigation into deliberate alteration of customer satisfaction survey data.
2004-03-31restructuringin_progress2004-03-31CaliforniaTransmission and DistributionMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE severed employment of several supervisory personnel in service planning group following investigation into data alteration.
2002-12-31restructuringcompletedIllinois, United StatesEME — Midwest Generation (Illinois plants)MD&A
f5-10k / GLM-5.3-flash-HTML
Temporary suspension of operations at four coal/gas units (Will County 1-2, Collins 4-5) at end of 2002 / January 2003 to cut operating costs; units maintained for possible return to service and no employee counts disclosed.
2002-12-31otherin_progressEdison O&M Services (nonutility O&M services business)Item_1_Business
f5-10k / GLM-5.3-flash-HTML
Decision made during 2002 to wind down the business, which was described as not material; no employee counts or charges disclosed.
2002-12-31restructuringin_progress2002-12-31United StatesEdison O&M Services (operations and maintenance services)Item_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
During 2002 Edison International decided to wind down the business; no headcount, charge, or completion date disclosed. Announcement date shown as fiscal year-end because only the year of decision is given.
2002-12-31plant_closureannounced2002-12-312003-01-01United States — IllinoisEdison Mission Energy — Midwest Generation (Will County Units 1 and 2; Collins Station Units 4 and 5)MD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Suspension of operations beginning January 2003 to reduce operating costs, driven by low wholesale prices; described as a suspension pending market improvement, not a permanent closure. No headcount impact quantified.
2002-12-31divestiture_reductioncompleted2002-03-312002-03-31United StatesEdison Mission Energy — equity-method energy projects (Commonwealth Atlantic, James River, Harbor)business_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Sales of 50% interests in Commonwealth Atlantic and James River and 30% interest in Harbor completed in Q1 2002 for $44 million proceeds; no gain or loss recorded. No headcount disclosed; equity-method stakes, so limited direct employee impact expected.
2002-12-31othercompleted2002-12-202002-12-20United KingdomEdison Mission Energy — Lakeland project (Lakeland Power Ltd.)discontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Project lenders appointed an administrative receiver on 2002-12-20, resulting in loss of control and deconsolidation; $92 million pre-tax ($77 million after-tax) impairment. No employee counts disclosed.
2002-09-30othercompleted2002-10-31United States (Illinois)Nonutility power generation (EME) — union-represented employees at Illinois plantsother
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME reached agreement with union-represented employees on a new retirement health care and other benefits plan (Jan 2003–Jun 2005) under which postretirement benefits will not be provided; EME will record a pre-tax gain of approximately $71 million in Q4 2002. No employee count disclosed.
2002-09-30otherannounced2002-10-25United States (Illinois)Nonutility power generation (EME) — turbine purchase contract terminationUSD 61 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME terminated equipment purchase contracts for nine turbines effective October 25, 2002, recording a $61 million pre-tax write-off of capitalized costs and reducing projected capex by $53 million. No employee count disclosed; action relates to capital commitments rather than headcount.
2002-09-30plant_closureannounced2002-09-302002-12-31United States (Illinois)Nonutility power generation (EME) — Will County Units 1&2 and Collins Station Units 4&5MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME announced suspension of operations at Will County Units 1 and 2 and Collins Station Units 4 and 5 beginning January 2003 to reduce operating costs. No employee count disclosed; EME notes possible future decommissioning charge if conditions persist.
2002-09-30restructuringcompleted2002-09-302002-09-30IllinoisEdison Mission Energy (EME)USD 25 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Write-off of capitalized costs associated with suspension of a capital environmental improvements project at EME's Illinois plants.
2002-09-30restructuringcompleted2002-09-302002-09-30PennsylvaniaEdison Mission Energy (EME)USD 61 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Write-off of capitalized costs associated with terminating agreements to purchase turbines from Siemens Westinghouse for Homer City plant.
2002-09-30othercompleted2002-10-012002-10-01IllinoisEdison Mission Energy (EME)subsequent_events
f5-10q / Qwen3.6-27B-Q8_0
EME reached an agreement with union-represented employees on a new retirement health care and other benefits plan, treating the prior plan as terminated. This resulted in a pre-tax gain of approximately $71 million recorded in Q4 2002.
2002-06-30restructuringannounced2002-03-31United StatesEME (Edison Mission Energy) — corporate and enterprise-wideMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
EME initiated a company-wide review of its organization, related costs, and overhead reductions; no employee count or charge disclosed.
2002-06-30plant_closureannounced2002-06-302003-01-01United States — IllinoisEME — Will County plant, Units 1 and 2MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Operations suspension announced for January 2003 pending improved market conditions; possible future decommissioning could trigger an income charge. No headcount disclosed.
2001-12-31divestiture_reductioncompleted2001-06-302001-10-18United StatesEdison Enterprises (retail products and services)discontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Edison Enterprises sold Edison Utility Services (Jan 2001), Edison Select to ADT Security (Aug 2001), and substantially all assets of Edison Source to management (Oct 2001). No employee counts disclosed for any of the three dispositions.
2001-12-31divestiture_reductioncompleted2001-12-212001-12-21United KingdomEdison Mission Energy — Ferrybridge and Fiddler's Ferry coal stationsdiscontinued_operations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Sale of the two UK coal stations to American Electric Power subsidiaries completed 2001-12-21 for GBP 643 million. No employee counts disclosed.
2001-12-31divestiture_reductioncompleted2001-12-312001-12-31United StatesEdison Mission Energy — non-strategic energy project interestsItem_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
EME agreed to sell five projects during 2001 to reduce debt; three sales (Commonwealth Atlantic, James River, Harbor) closed after year-end. No employee counts disclosed for any disposition.
2001-09-30otherin_progress2001-01-01CaliforniaSouthern California Edison CompanyMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE implemented cost-cutting measures including freezing new hiring.
2001-06-30divestiture_reductionannounced2001-06-072001-12-31United StatesEdison Enterprises — integrated energy outsourcingUSD 117 (millions)restructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
After-tax charge to reduce carrying value of assets held for sale; no employee count disclosed.
2001-06-30divestiture_reductioncompleted2001-06-272001-08-02United StatesEdison Enterprises — residential security servicesrestructuring_footnote
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Stock Purchase Agreement dated 2001-06-27; sale to ADT Security Services closed 2001-08-02. No employee count disclosed.
2001-03-31layoffin_progressUnited States (Southern California)Southern California Edison Company (SCE)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE cost-cutting measures, including freezing new hires and ceasing charitable contributions, were expected to impact about 1,450 to 1,850 jobs and affect service levels.
2001-03-31layoffannounced2001-03-15United States (Southern California)Southern California Edison Company (SCE) — service and reliability employeesMD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
CPUC issued an order rescinding SCE's layoffs of employees involved with service and reliability; SCE ordered to restore specified service levels and report on cost-cutting measures.
2001-03-31restructuringin_progress2001-03-15CaliforniaService and reliabilityMD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE implemented cost-cutting measures expected to impact 1,450 to 1,850 jobs. On March 15, 2001, the CPUC issued an order rescinding layoffs of employees involved with service and reliability and ordering restoration of specified service levels. The amount of cost savings affected by the order is not material.
2000-12-31restructuringin_progressCaliforniaSouthern California Edison CompanyMD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Range of 1,450–1,850 jobs; no single count disclosed. Included freezing new hires, postponing capital expenditures, ceasing charitable contributions. On 2001-03-15 CPUC rescinded layoffs of service/reliability employees. No severance charge quantified.
2000-12-31restructuringcompleted2001-01-01CaliforniaSouthern California Edison CompanyItem_1_Business
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
SCE implemented cost-cutting measures including freezing new hires and ceasing new charitable contributions. Actions expected to impact 1,450 to 1,850 jobs. CPUC later rescinded layoffs of employees involved with service and reliability.
2000-12-31restructuringcompleted2001-01-01CaliforniaSouthern California Edison CompanyMD&A
f5-10k / Qwen3.6-27B-Q8_0
SCE began immediate cost-cutting measures aimed at reducing general operating costs, expected to impact about 1,450 to 1,850 jobs. CPUC later rescinded layoffs of employees involved with service and reliability.
2000-09-30otherin_progressUnited StatesSouthern California Edison (electric utility)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE froze new hires as a cost-control measure amid liquidity pressure from transition revenue account undercollections; no employee count or duration disclosed.
1999-12-31restructuringcompleted1999Edison EnterprisesMD&A
f5-10k / GLM-5.3-flash-HTML
Actions taken during 1999 to close five Edison Enterprises businesses and refocus the ongoing businesses. The charge is quantified only as a one-time adjustment of 6 cents per share; employees affected and a dollar charge amount are not disclosed.
1999-12-31acquisition_additioncompleted1999-03United States (Pennsylvania)Edison Mission Energy (EME)business_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
EME completed the acquisition of the 1,884-MW Homer City Generating Station for approximately $1.8 billion in March 1999 and operates the plant. The date shown is the disclosed completion month; employees added were not disclosed.
1999-12-31acquisition_additioncompleted1999-05New ZealandEdison Mission Energy (EME)business_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
EME completed the acquisition of a 40% interest in Contact Energy Ltd. from the New Zealand government for approximately $635 million in May 1999. The date shown is the disclosed completion month; employees added were not disclosed.
1999-12-31acquisition_additioncompleted1999-07United KingdomEdison Mission Energy (EME)business_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
EME completed the acquisition of the Ferrybridge and Fiddler's Ferry coal-fired plants (3,886 MW combined) for approximately $2.0 billion in July 1999. The date shown is the disclosed completion month; employees added were not disclosed.
1999-12-31acquisition_additioncompleted1999-10United Kingdom (England)Edison Mission Energy (EME)business_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
EME acquired the remaining 20% of the 220-MW Roosecote gas-fired project for approximately $16 million in October 1999, having previously held an 80% interest. The date shown is the disclosed completion month; headcount impact was not disclosed.
1999-12-31acquisition_additioncompleted1999-12United States (Illinois)Edison Mission Energy (EME) — Midwest Generation LLCbusiness_combinations_footnote
f5-10k / GLM-5.3-flash-HTML
EME, through Midwest Generation LLC, completed the acquisition of Commonwealth Edison's fossil-fueled plants (9,510 MW including the leased Collins Station) in a $4.9 billion transaction in December 1999. The date shown is the disclosed completion month; employees added were not disclosed.
1999-12-31restructuringcompletedUnited StatesEdison EnterprisesMD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Five businesses closed; one-time charge of 6¢ per share. No employee count or specific dates disclosed.
1999-12-31acquisition_additioncompleted1999-03-011999-03-31United StatesEdison Mission Energybusiness_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Acquisition of 1,884-MW Homer City plant for ~$1.8B. No headcount added disclosed.
1999-12-31acquisition_additioncompleted1999-05-011999-05-31New ZealandEdison Mission Energybusiness_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Acquisition of 40% of Contact Energy for ~$635M. No headcount added disclosed.
1999-12-31acquisition_additioncompleted1999-07-011999-07-31United KingdomEdison Mission Energybusiness_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Acquisition of two UK coal plants (3,886 MW combined) for ~$2.0B. No headcount added disclosed.
1999-12-31acquisition_additioncompleted1999-12-151999-12-31United StatesEdison Mission Energybusiness_combinations_footnote
f5-10k / MiMo-V2.6-Flash-fp8-HTML
$4.9B transaction for 9,510 MW of generating capacity. No headcount added disclosed.
1998-06-30restructuringin_progress2006-12-31CaliforniaSouthern California Edison CompanyMD&A
f5-10q / Qwen3.6-27B-Q8_0
Statute mandates recovery of employee-related transition costs for retraining, severance, early retirement, and outplacement through 2006.
1997-12-31divestiture_reductionannouncedCentral and Southern CaliforniaSCE oil- and gas-fueled fossil generation plantsItem_1_Business
f5-10k / GLM-5.3-flash-HTML
SCE agreed to sell 11 of 12 fossil plants for $1.1 billion, with ownership transfer expected by March 31, 1998 (after fiscal year-end). SCE will operate divested plants for at least two years post-sale and will offer workforce transition programs to employees impacted by divestiture-related job reductions. No headcount affected is disclosed. Restructuring legislation provides rate recovery through 2006 of employee-related transition costs (retraining, severance, early retirement, outplacement).
1997-12-31acquisition_additioncompleted1997Edison Capital — affordable housing managementItem_1_Business
f5-10k / GLM-5.3-flash-HTML
Edison Capital acquired the John Stewart Company, a diversified management company specializing in affordable housing. Headcount added through the acquisition is not disclosed.
1997-12-31divestiture_reductionin_progress1996-11-011998-03-31CaliforniaSCE — Generation (oil- and gas-fueled plants)Item_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
SCE agreed to sell 11 of 12 oil/gas generating plants; workforce transition programs offered to impacted employees. No specific employee count disclosed.
1997-12-31restructuringcompleted1996-09-01CaliforniaSouthern California Edison CompanyItem_1_Business
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Filing mentions 'workforce transition programs' offered to employees impacted by divestiture-related job reductions following the sale of gas-fueled generating plants. Specific headcount or charges not disclosed.
1997-12-31voluntary_separationcompleted1997-01-011997-12-31CaliforniaSouthern California Edison CompanyItem_1_Business
f5-10k / Qwen3.6-27B-Q8_0
Legislation mandated recovery of reasonable employee-related transition costs for retraining, severance, early retirement, and outplacement. SCE offered workforce transition programs for employees impacted by divestiture-related job reductions.
1997-06-30othercompleted1996-09-301997-09-30CaliforniaHuman ResourcesUSD 8 (millions)Legal Proceedings
f5-10q / Qwen3.6-27B-Q8_0
Settlement of racial discrimination lawsuit; $8.15 million fund for back pay claims established.
1997-06-30otherin_progress1997-06-30CaliforniaGeneralLegal Proceedings
f5-10q / Qwen3.6-27B-Q8_0
Consent Decree approved; seven-year term with possibility of early termination after five years.
1997-03-31voluntary_separationcompletedCaliforniaSouthern California Edison CompanyMD&A
f5-10q / Qwen3.6-27B-Q8_0
Lower payroll taxes related to workforce reductions after SCE's voluntary retirement programs in 1996.
1997-03-31voluntary_separationin_progress2006-12-31CaliforniaSouthern California Edison CompanyMD&A
f5-10q / Qwen3.6-27B-Q8_0
Legislation contains provisions for recovery of reasonable employee-related transition costs incurred and projected for retraining, severance, early retirement, outplacement and related expenses through 2006.
1996-12-31voluntary_separationcompleted3,0001996Edison International company-wide (primarily SCE)USD 7 (millions)Item_1_Business
f5-10k / GLM-5.3-flash-HTML
Voluntary retirement program offered during 1996 to eligible employees; approximately 2,200 non-represented and 800 represented employees accepted. Net expense of $7 million is after allowance for pension settlement effects (Note 6 discloses a $121 million SCE pension settlement gain in 1996).
1996-12-31divestiture_reductionannounced1996-11-27SCE — all oil- and gas-fueled generation assets (12 plants)Item_1_Business
f5-10k / GLM-5.3-flash-HTML
SCE filed a CPUC application on November 27, 1996 to divest by auction all oil- and gas-fueled generation assets; also announced via Form 8-K dated December 5, 1996. SCE would offer workforce transition programs to employees impacted by divestiture-related job reductions; headcount impact not quantified. CPUC approval requested for late 1997 and proposal contingent on restructuring proceeding satisfactorily.
1996-12-31acquisition_additioncompleted1996United States (Boston, Massachusetts-based target)Edison Capital — affordable housing businessItem_1_Business
f5-10k / GLM-5.3-flash-HTML
Edison Capital acquired East Coast Capital, a privately held low-income housing tax credit syndicator, during 1996; headcount added through the acquisition not disclosed.
1996-12-31voluntary_separationcompleted3,0001996-01-011996-12-31United StatesEdison International and subsidiariesUSD 7 (millions)Item_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Voluntary retirement program; 2,200 non-represented and 800 represented employees accepted. Net expense of $7 million after pension settlement gains. Announcement date approximate (during 1996).
1996-12-31voluntary_separationcompleted3,0001996-01-011996-12-31United StatesEdison International and SubsidiariesUSD 7 (millions)Item 1. Business
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
Voluntary retirement program offered to eligible employees. Approximately 3,000 employees accepted (2,200 non-represented and 800 represented). Net expense was $7 million after pension settlement gains.
1996-12-31voluntary_separationcompleted3,0001996-01-011996-12-31United StatesEdison International and SubsidiariesUSD 7 (millions)Item 1_Business
f5-10k / Qwen3.6-27B-Q8_0
Voluntary retirement program accepted by approximately 3,000 employees (2,200 non-represented and 800 represented). Net expense was $7 million after allowance for pension settlement gains.
1996-12-31voluntary_separationcompleted3,000United StatesEdison International (2,200 non-represented and 800 represented employees accepted)USD 7 (millions)Item_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Program offered during 1996; net expense of $7 million after allowance for pension settlement gains at SCE. MD&A also cites a 4-cent-per-share 1996 special charge at SCE for workforce management costs and reserves without headcount detail; not extracted separately to avoid double-counting. No announcement or completion dates stated.
1996-09-30voluntary_separationin_progress3,4001996-08-011996-12-31United States (Southern California)Southern California Edison Company (SCE)USD 26 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
SCE voluntary retirement program; 2,400 non-represented and 1,000 represented employees. Represented employees voted to accept in August 1996; elections irrevocable 1996-09-30. $26M total expensed in 1996, including $12M additional accrual in Q3 for represented employees.
1996-09-30restructuringcompleted1996-07-011996-09-30United States (Southern California)Southern California Edison Company (SCE)USD -40 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Reversal of $40M pre-tax charge accrued in Q2 1996 for outsourcing certain operations; SCE decided not to outsource in Q3. Partially offset by $12M additional voluntary retirement accrual.
1996-09-30voluntary_separationin_progress3,4001996-08-011996-12-31CaliforniaSouthern California Edison Company (SCE)USD 26 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE expects to reduce workforce by approx. 3,400 employees (2,400 non-represented, 1,000 represented) by year-end 1996 via voluntary retirement program. Total expensed amount in 1996 is $26 million. Elections became irrevocable on Sept 30, 1996.
1996-06-30restructuringin_progress3,1001996-04-011996-12-31United States (Southern California)Southern California Edison — nonrepresented workforceUSD 54 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
One-time charge recorded in Q2 1996 for workforce management costs; includes voluntary retirement offer and outsourcing of certain operations.
1996-06-30voluntary_separationannounced1996-06-301996-12-31United States (Southern California)Southern California Edison — represented workforceUSD 16 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Tentative agreement subject to ratification for voluntary retirement program for represented employees; could increase total charge to approximately $70 million by year-end 1996. Incremental charge of ~$16M implied by difference from $54M base charge.
1996-06-30restructuringin_progress3,1001996-06-301996-12-31CaliforniaNonrepresented workforceUSD 54 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE recorded a one-time charge of $54 million for workforce management costs related to reducing nonrepresented workforce by approx. 3,100 employees via voluntary retirement and outsourcing.
1996-06-30voluntary_separationannounced1996-06-301996-12-31CaliforniaRepresented workforceUSD 16 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Tentative agreement on voluntary retirement program for represented employees; total charge could increase to approx. $70 million (implying additional $16 million) depending on acceptance.
1996-03-31voluntary_separationannounced1996-03-31United StatesSouthern California Edison Company (SCE) — non-union employeesUSD 65 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Announced March 1996; pre-tax charge to be taken in Q2 1996. SCE expects to offset costs through lower expenses within a year. A similar program for represented employees could raise total charge to ~$100M pre-tax by year-end. Number of employees accepting the offer not yet disclosed.
1996-03-31voluntary_separationannounced1996-03-31CaliforniaSouthern California Edison Company (SCE)USD 65 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
SCE announced a one-time charge of approx $65 million (pre-tax) in Q2 1996 for a voluntary retirement offer for non-union employees. Total charge may increase to $100 million if a similar program for represented employees is negotiated. Actual headcount depends on acceptance.
1995-12-31reduction_in_forcecompleted567California, United StatesSouthern California Edison Company (electric utility)USD 25 (millions)MD&A
f5-10k / GLM-5.3-flash-HTML
SCE severed 567 employees during 1995, representing about $42 million of total annualized labor costs. Severance charges of $25 million were recorded in 1995 ($30 million in 1994) and comprise cash payments for services plus a non-cash benefit component. SCE anticipates continued workforce reductions as it positions for a more competitive operating environment, with savings expected to reduce other operating expenses in 1996.
1995-12-31voluntary_separationannounced1996-03-22California, United StatesSouthern California Edison Company — full-time, non-union employeesUSD 65 (millions)subsequent_events
f5-10k / GLM-5.3-flash-HTML
Voluntary early retirement program for full-time, non-union SCE employees announced March 22, 1996, after fiscal year-end; disclosed in Item 1 (Business of SCE). Approximately $65 million pretax charge to be recorded against second quarter 1996 earnings, with program costs expected to be offset by savings within a year. SCE also anticipates negotiating a program for represented employees with its four labor unions later in 1996.
1995-12-31reduction_in_forcecompleted567Southern CaliforniaSouthern California Edison Company (SCE)USD 25 (millions)MD&A
f5-10k / MiMo-V2.6-Flash-fp8-HTML
SCE severed 567 employees in 1995; annualized labor cost savings of about $42 million. Severance charges of $25 million recorded in 1995.
1995-12-31voluntary_separationannounced1996-03-22Southern CaliforniaSouthern California Edison Company (SCE) — full-time non-union employeesUSD 65 (millions)Item_1_Business
f5-10k / MiMo-V2.6-Flash-fp8-HTML
Voluntary early retirement program announced after fiscal year-end; pretax charge to be recorded against Q2 1996 earnings. Number of participants not disclosed.
1995-12-31voluntary_separationcompleted5671995-01-011995-12-31CaliforniaSouthern California Edison CompanyUSD 25 (millions)MD&A
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
SCE severed 567 employees in 1995 representing annualized labor costs of about $42 million. Severance charges recorded were $25 million. Program designed to meet workforce needs while maintaining commitments to customer service.
1995-12-31voluntary_separationannounced1996-03-22CaliforniaSouthern California Edison CompanyUSD 65 (millions)subsequent_events
f5-10k / Qwen3.6-27B-NVFP4-MTP-HTML
On March 22, 1996, SCE announced a voluntary early retirement program for full-time, non-union employees. SCE will record a charge of approximately $65 million (pretax) against second quarter 1996 earnings. This is a subsequent event relative to the 1995 fiscal year-end.
1995-12-31voluntary_separationannounced1996-03-22CaliforniaSouthern California Edison Company (SCE)USD 65 (millions)Item_1_Business
f5-10k / Qwen3.6-27B-Q8_0
Voluntary early retirement program for full-time, non-union employees announced March 22, 1996. Pretax charge of $65 million recorded against second quarter earnings. Negotiations with four labor unions for represented employees expected later in 1996.
1995-12-31restructuringcompleted5671995-01-011995-12-31CaliforniaSouthern California Edison Company (SCE)USD 25 (millions)MD&A
f5-10k / Qwen3.6-27B-Q8_0
SCE severed 567 employees in 1995 representing total annualized labor costs of about $42 million. Severance charge of $25 million recorded in 1995.
1995-09-30restructuringin_progressUnited StatesSouthern California Edison CompanyUSD 12 (millions)MD&A
f5-10q / MiMo-V2.6-Flash-fp8-HTML
Severance charges of $12 million recorded in other operating expenses for the nine months ended September 30, 1995; no employee count disclosed. Filer anticipates continued workforce reductions but states no company-wide reduction plan meeting restructuring-reporting criteria exists.
1995-09-30restructuringin_progressCaliforniaEdisonUSD 12 (millions)MD&A
f5-10q / Qwen3.6-27B-Q8_0
Severance charges incurred for nine-month period; workforce reductions anticipated to continue but not classified as financial reporting restructuring.