Table of Contents Worksheet Name Overview BaseTRR IFPTRR TrueUpAdjust TUTRR ROR PlantInService PlantStudy AccDep ADIT CWIP PHFU AbandonedPlant WorkCap IncentivePlant IncentiveAdder PlantAdditions Depreciation DepRates OandM AandG RevenueCredits NUCs RegAssets CWIPTRR WholesaleDifference TaxRates Allocators FFU WholesaleTRRs Wholesale Rates HVLV GrossLoad RetailRates Schedule 3 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 33 Purpose Base TRR Components. Full Development of Retail and Wholesale Base TRRs. Calculation of the Incremental Forecast Period TRR Calculation of the True Up Adjustment Calculation of the True Up TRR Determination of Capital Structure Determination of Plant In Service balances Summary of Split of T&D Plant into ISO and NonISO Calculation of Accumulated Depreciation Calculation of Accumulated Deferred Income Taxes Presentation of Prior CWIP and Forecast Period Incremental CWIP. Calculation of Plant Held for Future Use Calculation of Abandoned Plant Calculation of Materials and Supplies and Prepayments Summary of Incentive Plant balances in the Prior Calculation of Incentive Adder component of the Prior TRR Forecast Additions to Net Plant Calculation of Depreciation Expense Presentation of Depreciation Rates Calculation of Operations and Maintenance Expense Calculation of Administrative and General Expense Calculation of Revenue Credits Calculation of Network Upgrade Credits and Network Upgrade Interest Expense Calculation of Regulatory Assets/Liabilities and Regulatory Debits Calculation of Contribution of CWIP to TRRs Calculation of the Wholesale Difference to the Base TRR Calculation of Composite Tax Rate Calculation of Allocation Factors Calculation of Franchise Fees Factor and Uncollectibles Expense Factor Calculation of components of SCE's Wholesale TRR Calculation of SCE's Wholesale transmission rates Calculation of High and Low Voltage percentages of Gross Plant Presentation of forecast Gross Load for wholesale rate calculations Calculation of retail transmission rates
Overview Overview of SCE Retail Base TRR SCE's retail Base Transmission Revenue Requirement is the sum of the following components: TRR Component Prior TRR Incremental Forecast Period TRR TrueUp Adjustment Forecast Adjustment Base TRR (retail) Amount These components represent the following costs that SCE incurs: ) The Prior TRR component is the TRR associated with the Prior (most recent calendar year). The Prior TRR is calculated using Endof Rate Base values, as set forth in the "BaseTRR" Worksheet. ) The Incremental Forecast Period TRR is the component of Base TRR associated with forecast additions to inservice plant or CWIP, as set forth in the "IFPTRR" Worksheet. 3) The True Up Adjustment is a component of the Base TRR that reflects the difference between projected and actual costs, as set forth in the "TrueUpAdjust" Worksheet. ) The Forecast Adjustment component may be included as provided in the Tariff protocols.
Schedule Base TRR Southern California Edison Company Cells shaded yellow are input cells Formula Transmission Rate Notes FERC Form Reference or Instruction Value RATE BASE 3 ISO Transmission Plant General Plant + Electric Miscellaneous Intangible Plant Transmission Plant Held for Future Use Abandoned Plant PlantInService WS, 9 PlantInService WS, 7 PHFU WS, 8 AbandonedPlant WS, 3 5 7 Working Capital amounts Materials and Supplies Prepayments Cash Working Capital WorkCap WS, 5 WorkCap WS, ( 5 + ) / 8 5 + + 7 AccDep WS, 3, Col. AccDep WS,, Col. 5 AccDep WS, 9 + 0 + ADIT WS, 5, Col. 8 9 0 Working Capital Accumulated Depreciation Reserve Balances Transmission Depreciation Reserve ISO Distribution Depreciation Reserve ISO General + Intangible Plant Depreciation Reserve Negative amount Negative amount Negative amount Accumulated Depreciation Reserve 3 Accumulated Deferred Income Taxes CWIP Plant IncentivePlant WS,, 5 Other Regulatory Assets/Liabilities RegAssets WS, Network Upgrade Credits NUCs WS, 5 7 Rate Base L + L + L3 + L + L8 + L + L3 + L+ L5+ L FF 3. (see note to left) Allocators WS, 8 * 9 3 + + 5 FF 3 (see note to left) FF 3 (see note to left) FF 3 (see note to left) FF 3 (see note to left) FF 3 (see note to left) FF 3. (see note to left) FF 3. (see note to left) + ( to 9) TaxRates WS, 50 30 3 Allocators WS, 9 3 * 33 0 + 3 Negative amount Negative amount OTHER TAXES 8 9 0 Property Taxes Transmission Plant Allocation Factor Property Taxes 3 5 7 8 9 30 3 3 33 3 Payroll Taxes Expense FICA Fed Ins Cont Amt Current FICA/OASDI Emp Incntv. FICA/HIT Emp Incntv. SUI FUTA CADI Vol Plan Assess SF Payroll Expense Tax SCE Electric Payroll Tax Expense Capitalized Overhead portion of Electric Payroll Tax Expense Remaining Electric Payroll Tax Expense to Allocate Transmission Wages and Salaries Allocation Factor Payroll Taxes Expense 35 Other Taxes Row _, Column i Row _, Column i Row _, Column i Row _, Column i Row _, Column i Row _, Column i Row _, Column i Row _, Column i
Schedule Base TRR Southern California Edison Company Cells shaded yellow are input cells Formula Transmission Rate Notes FERC Form Reference or Instruction Value RETURN AND CAPITALIZATION CALCULATIONS 3 37 38 Debt Long Term Debt Amount Cost of Long Term Debt Long Term Debt Cost Percentage ROR WS, ROR WS, 0 ROR WS, 39 0 Preferred Stock Preferred Stock Amount Cost of Preferred Stock Preferred Stock Cost Percentage ROR WS, 5 ROR WS, 9 ROR WS, 30 Equity Common Stock Equity Amount ROR WS, 3 3 Capital 3 + 39 + 5 Capital Percentages Long Term Debt Capital Percentage Preferred Stock Capital Percentage Common Stock Capital Percentage 7 8 9 Annual Cost of Capital Components Long Term Debt Cost Percentage Preferred Stock Cost Percentage Return on Equity 50 5 5 53 Calculation of Cost of Capital Rate Weighted Cost of Long Term Debt Weighted Cost of Preferred Stock Weighted Cost of Common Stock Cost of Capital Rate 5 55 Equity Rate of Return Including Preferred Stock Note Used for Tax calculation Return on Capital: Rate Base times Cost of Capital Rate 3 / 3 39 / 3 / 3 + 5+ 38 SCE Return on Equity 38 * * 5 * 9 50 + 5 + 5 5 + 5 7 * 53 0.3 INCOME TAXES 5 57 58 Federal Income Tax Rate State Income Tax Rate Composite Tax Rate 59 0 Calculation of Credits and Other: Amortization of Excess Deferred Tax Liability Investment Tax Credit Flowed Through South Georgia Income Tax Adjustment Credits and Other 3 Income Taxes: Income Taxes = [(RB * ER) * (CTR/( CTR))] + CO/( CTR) Where: RB = Rate Base ER = Equity Rate of Return Including Preferred Stock CTR = Composite Tax Rate CO = Credits and Other = F + [S * ( F)] Tax Rates WS, Tax Rates WS, 8 (L5 + L57) (L5 * L57) 59 + 0+ 00 50,000,0,000,08,00 Note Note Note Formula on
Schedule Base TRR Southern California Edison Company Cells shaded yellow are input cells Formula Transmission Rate Notes FERC Form Reference or Instruction Value PRIOR YEAR TRANSMISSION REVENUE REQUIREMENT 5 7 8 9 70 7 7 73 7 75 7 Component of Prior TRR: O&M Expense A&G Expense Network Upgrade Interest Expense Depreciation Expense Abandoned Plant Amortization Expense Other Taxes Revenue Credits Return on Capital Income Taxes Gains and Losses on Trans. Plant Held for Future Use Land Regulatory Debits Prior Incentive Adder 77 OandM WS, 35, Col. AandG WS, 3 NUCs WS, 0 Depreciation WS, 70 AbandonedPlant WS, 35 Revenue Credits WS, 5 55 3 PHFU WS, 0 RegAssets WS, IncentiveAdder WS, without FF&U Sum of s 5 to 7 78 79 Franchise Fees Expense Uncollectibles Expense 77 * FF (from FFU WS) 77 * U (from FFU WS) 80 Prior TRR 77 + 78+ 79 80 IFPTRR WS, 8 TrueUpAdjust WS, 0 L 8 + L 8 + L 83 + L 85 Negative amount Gain negative, loss positive TOTAL BASE TRANSMISSION REVENUE REQUIREMENT 8 8 83 8 85 Calculation of Base Transmission Revenue Requirement Prior TRR Incremental Forecast Period TRR True Up Adjustment Note 3 Initial Prior?: If Initial Prior, enter "Yes", else "No" Forecast Adjustment Note 8 Base Transmission Revenue Requirement (Retail) 87 88 Wholesale Base Transmission Revenue Requirement Base TRR (Retail) Wholesale Difference to the Base TRR 8 WholesaleDifference WS, 3 89 Wholesale Base Transmission Revenue Requirement 87 + 88 For Retail Purposes Notes: ) No change in Return on Equity will be made absent a filing at the Commission. Includes 50 basis point ISO Participation Adder. Does not include any projectspecific ROE adders. ) No change in "Credits and Other" terms will be made absent a filing at the Commission 3) The True Up Adjustment for the initial Base TRR is 0. ) Forecast Adjustment may be included as provided in the Tariff protocols.
Schedule Incremental Forecast Period TRR Calculation of Incremental Forecast Period TRR ("IFPTRR") The IFP TRR is equal to the sum of: ) Forecast Plant Additions * AFCR ) Forecast Period Incremental CWIP * AFCR for CWIP ) Calculation of Annual Fixed Charge Rates: 3 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 33 3 35 3 37 38 39 0 3 5 7 8 9 50 5 5 53 5 55 5 57 a) Annual Fixed Charge Rate for CWIP ("AFCRCWIP") AFCRCWIP represents the return and income tax costs associated with of CWIP, expressed as a percent. AFCRWIP = CLTD + (COS * (/( CTR))) where: CLTD = Weighted Cost of Long Term Debt COS = Weighted Cost of Common and Preferred Stock CTR = Composite Tax Rate Wtd. Cost of Long Term Debt: Wtd. Cost of Common + Pref. Stock: Composite Tax Rate: Reference BaseTRR WS, 50 BaseTRR WS, 5 BaseTRR WS, 58 AFCRCWIP = + ( 3 * (/( )) b) Annual Fixed Charge Rate ("AFCR") The AFCR is calculated by dividing the Prior TRR (without CWIP related costs) by Net Plant: AFCR = (Prior TRR CWIPrelated costs) / Net Plant Determination of Net Plant: Transmission Plant ISO: Distribution Plant ISO: Transmission Dep. Reserve ISO: Distribution Dep. Reserve ISO: Net Plant: Reference PlantInService WS, 3 PlantInService WS, AccDep WS, 3 AccDep WS, (L7 + L8) (L9 + L30) Determination of Prior TRR without CWIP related costs: a) Determination of CWIPRelated Costs ) Direct (without ROE adder) CWIP costs CWIP Plant Prior : AFCRCWIP: Direct CWIP Related Costs: CWIP WS, L 3 C 9 * 50 IREF: IncentiveAdder WS, 3 CWIP WS, 3 IncentiveAdder WS, 5 Below formula ) CWIP ROE Adder costs: Tehachapi CWIP Amount: Tehachapi ROE Adder : Tehachapi ROE Adder : DCR CWIP Amount: DCR ROE Adder : DCR ROE Adder : CWIP WS, 3 IncentiveAdder WS, Formula on 5 ROE Adder = (CWIP/,000,000) * IREF * (ROE Adder/) CWIP Related Costs wo FF&U: FF&U Expenses: CWIP Related Costs with FF&U: 39 + + 50 FF + U Factors from FFU WS 5 + 55
Schedule Incremental Forecast Period TRR 58 b) Determination of AFCR: 59 0 CWIP Related Costs: Prior TRR: Prior TRR wo CWIP Related Costs: 3 AFCR: 5 ) Calculation of IFP TRR 7 8 Forecast Plant Additions: 9 AFCR: 70 AFCR * Forecast Plant Additions: 7 7 Forecast Period Incremental CWIP: 73 AFCRCWIP: 7 AFCRCWIP * FP Incremental CWIP: 75 7 IFPTRR without FF&U: 77 78 Franchise Fees Expense: 79 Uncollectibles Expense: 80 8 Incremental Forecast Period TRR: 5 BaseTRR WS, 8 0 / 3 Reference PlantAdditions WS, L, C 3 8 * 9 CWIP WS, L 9, C 7 * 73 70 + 7 7 * FF (from FFU WS) 7 * U (from FFU WS) 7 + 78 + 79
Schedule 3 True Up Adjustment Calculation of True Up Adjustment Component of TRR ) Summary of True Up Adjustment calculation: a) Attribute True Up TRR to months in the Prior (see Note #) to determine "ly True Up TRR" for each month (see Note #). If formula was not in effect in Prior, do not populate Column or 3, s to. b) Determine monthly retail transmission revenues attributable to this formula transmission rate received during Prior. c) Compare costs in (a) to revenues in (b) on a monthly basis and determine "Cumulative Excess () or Shortfall (+) in Revenue with Interest". d) Continue interest calculation through the end of the previous Rate Effective Period ( 3). e) Amortize this ending balance from (d) over the current Rate Effective Period so that the ending balance on 5 is equal to 0. ) Comparison of True Up TRR and Actual Retail Transmission Revenues received during the Prior, Including previous year True Up Adjustment. 3 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 True Up TRR: 0 See Note Calculations: : From TUTRR WS, See Note 3 Col See Note = C C3 + C Col See Note 5 One Time and February September October November February September ly True Up TRR Actual Retail Base Transmission Revenues Previous Period True Up Adjustment ly Excess () or Shortfall (+) in Revenue NA NA NA NA NA NA NA NA ly Interest Rate Col 7 See Note Cumulative Excess () or Shortfall (+) in Revenue wo Interest for Current Col 8 See Note 7 Col 9 =C7 + C8 Interest for Current Cumulative Excess () or Shortfall (+) in Revenue with Interest
Schedule 3 True Up Adjustment 33 3) Amortization of September balance over Rate Effective Period: 3 35 See Note 8 3 37 ly 38 Interest 39 Rate 0 October November 3 February 5 7 8 9 50 5 September 5 53 5 55 5 ) True Up Adjustment 57 58 One Time Adjustments: 59 Shortfall or Excess Revenue in Prior : See Note 9 Col See Note 0 =C3 + C Col 7 =C5 + C Interest for Current Col 8 = C Beginning Balance Ending Balance Amortization wo Interest True Up Adjustment Received (+)/ Returned ( ) Ending Balance Shortfall or Excess Revenue in Prior : Amortization in Rate Effective Period (See Instruction #): Col See Note Notes:, Col.. Also, see instruction 5. Column 8, 5 0 True Up Adjustment: 58 + 59. Positive amount is to be collected by SCE (included in Base TRR as a positive amount). Negative amount is to be returned to customers by SCE (included in Base TRR as a negative amount). 5) Final True Up Adjustment 3 The Final True Up Adjustment begins on the month after the last True Up Adjustment and extends through the termination date of this formula transmission rate. 5 The Final True Up Adjustment shall be calculated as above, with interest to the termination date of the Formula Transmission Rate.
Schedule 3 True Up Adjustment 7 8 9 70 7 7 73 7 75 7 77 78 79 80 8 8 83 8 85 8 87 88 89 90 9 9 93 9 95 9 97 98 99 00 0 0 03 0 05 0 07 Partial TRR Attribution Allocation Factors: Partial TRR AAF Note:.37 See Note. February 5.55 7.83 8. 8.08 8.95 9.89 0. September 0.8 October 9.79 November 7.530 8.0 : 00.000 Transmission Revenues: (Note ) See Note 3 Prior Jan Feb Mar Apr Jun Jul Aug Sep Oct Nov Dec s: Actual Retail Base Transmission Revenues See Note Other Transmission Col Distribution Public Purpose Generation Col Col 7 Sum of left ly Retail Revenue Other " Sales to Ultimate Consumers" from FERC Form Page 300, 0, Column b:
Schedule 3 True Up Adjustment Instructions: ) Enter applicable years on Column, s 3 and 05. ) Enter Previous Period True Up Adjustment (if any) on Column, s 03. See Note for definition of Previous Period True Up Adjustment. Enter with the same sign as in previous Informational Update. If there is no Previous Period True Up Adjustment, then enter 0 in these cells. 3) Enter monthly interest rates in accordance with interest rate specified in the regulations of FERC at 8 C.F.R. 35.9a on lines to 3, Column. If interest rate for any months not known, use most recent known month. ) Enter " Amortization" amount on 5, column to set September Ending Balance Column 7, 5 equal to 0. Iterate if necessary to solve. (i.e., so that the Beginning Balance in Column 3, 0 is completely amortized away by the Amortization amounts in Column ). 5) Enter any One time Adjustments on Column, and 58. If SCE is owed enter as positive, if SCE is to return to customers enter as negative. One time adjustments include: a) Enter CWIP mechanism final balance in first True Up Adjustment calculation in accordance with tariff protocols. b) In the event that a Commission Order revises SCE's True Up TRR for a previous Prior, SCE shall also include that difference in the True Up Adjustment, including interest, at the first opportunity, in accordance with tariff protocols. Entering on ensures these One time Adjustments are recovered from or returned to customers. Entering on 58 ensures that transmission rates for the Rate Effective Period will reflect these One Time Adjustments. c) Any refunds attributable to SCE's previous CWIP TRR cases (Docket Nos. ER08375, ER0987, ER00, and ER95), not previously returned to customers. ) Fill in matrix of all retail revenues from Prior in table on lines 93 to 0. 7) Enter Sales to Ultimate Consumers on line 07 and verify that it equals the total on line 05. 8) If true up period is less than entire calendar year, then adjust calculation accordingly by including 0 ly True Up TRR and for Actual Retail Base Transmission Revenues for any months not included in True Up Period. Notes: ) The true up period is the portion (all or part) of the Prior for which the Formula Transmission Rate was in effect. ) The ly True Up TRR is derived by multiplying the annual True Up TRR on by /, if formula was in effect. In the event of a Partial True Up, use the Partial TRR Attribution Allocation Factors on s 70 to 8 for each month of Partial True Up. Only enter in the Prior, s to, or portion of year formula was in effect in case of Partial True Up. 3) "Actual Retail Base Transmission Revenues" are SCE retail transmission revenues attributable to this formula transmission rate. as shown on s 93 to0, Column. ) The "Previous Period True Up Adjustment" are the values of the "True Up Adjustment Received/Returned" in the previous Informational Filing (Same sign). These are the monthly values of the "True Up Adjustment Received/Returned" in Column 8, s 0 5 from the previous Informational Filing, They are input into Column, lines 03 of this current Informational Filing, corresponding to the Rate Effective Period of the previous Informational Filing. One time True Up Adjustment amounts (see Instruction #5) attributable to a previous Prior are entered on Column,. 5) ly Interest Rates in accordance with interest rate specified in the regulations of FERC (See Instruction #3). ) "Cumulative Excess () or Shortfall (+) in Revenue wo Interest for Current " is: ) in month, the amount in Column 5; and ) in subsequent months is the amount in Column 9 for previous month plus the current month amount in Column 5. 7) Interest for Current is calculated on average of beginning and ending balances (Column 9 previous month and Column 7 current month). (First month average is / of ending balance). 8) The Interest Rate in Rate Effective Period is equal to average of interest rates in previous months (lines 03). 9) The " Beginning Balance" is Ending Balance from previous month in Column 7 (October is from Column 9, 3). 0) Amortization equals amount in 5 divided by each month. See Instruction # also for further detail. ) Interest for Current is calculated on average of beginning and end balances (wo interest) in Columns 3 and 5. ) Only provide if formula was in effect during Prior. 3) Only include Base Transmission Revenue attributable to this formula transmission rate. Any other Base Transmission Revenue or refunds is included in "Other". ) Other Transmission Revenue includes the following: a) Transmission Revenue Balancing Account Adjustment revenue b) Transmission Access Charge Balancing Account Adjustment c) Reliability Services Revenue d) Any Base Transmission Revenue not attributable to this formula.
Schedule True Up Prior TRR Calculation of True Up TRR A) Rate Base for True Up TRR 3 Rate Base Item ISO Transmission Plant General + Elec. Misc. Intangible Plant Transmission Plant Held for Future Use Abandoned Plant Calculation Method 3 Avg. BOY/EOY Avg. BOY/EOY Avg. BOY/EOY Avg. 5 7 8 Working Capital Amounts Materials and Supplies Prepayments Cash Working Capital Working Capital BOY/EOY Avg. BOY/EOY Avg. /8 (O&M + A&G) 9 0 Accumulated Depreciation Reserve Amounts Transmission Depreciation Reserve ISO Distribution Depreciation Reserve ISO G + I Depreciation Reserve Accumulated Depreciation Reserve 3 Avg. BOY/EOY Avg. BOY/EOY Avg. 3 5 Accumulated Deferred Income Taxes CWIP Plant Network Upgrade Credits Other Regulatory Assets/Liabilities 3 Avg. 3 Avg. BOY/EOY Avg. BOY/EOY Avg. 7 Rate Base Notes Negative amount Negative amount Negative amount Negative amount FERC Form Reference or Instruction PlantInService WS, 8 PlantInService WS, PHFU WS, 9 AbandonedPlant WS WorkCap WS, WorkCap WS, Base TRR WS 7 5 + + 7 AccDep WS,, Col. AccDep WS, 7, Col. 5 AccDep WS, 3 9 + 0 + ADIT WS, 5 IncentivePlant WS, L, C NUCs WS, 9 RegAssets WS, 5 L+L+L3+L+L8+L+ L3+L+L5+L Amount
Schedule True Up Prior TRR b) Return on Capital 8 9 Cost of Capital Rate Return on Capital: Rate Base times Cost of Capital Rate Base TRR WS L 53 7 * 8 c) Income Taxes 0 3 Income Taxes = [(RB * ER) * (CTR/( CTR))] + CO/( CTR) Where: RB = Rate Base ER = Equity Rate of Return including Preferred Stock CTR = Composite Tax Rate CO = Credits and Other 7 Base TRR WS L 5 Base TRR WS L 58 Base TRR WS L d) True Up TRR Calculation 5 7 8 9 30 3 3 33 3 35 3 O&M Expense A&G Expense Network Upgrade Interest Expense Depreciation Expense Abandoned Plant Amortization Expense Other Taxes Revenue Credits Return on Capital Income Taxes Gains and Losses on Transmission Plant Held for Future Use Land Regulatory Debits without True Up Incentive Adder Base TRR WS L 5 Base TRR WS L Base TRR WS L 7 Base TRR WS L 8 Base TRR WS L 9 Base TRR WS L 70 Base TRR WS L 7 9 0 Base TRR WS L 7 Base TRR WS L 75 Sum 5 to 35 37 True Up Incentive Adder IncentiveAdder WS L 0 38 True Up TRR without Franchise Fees Expense included: 3 + 37 3) Calculation of final True Up TRR with Franchise Fees 39 0 True Up TRR wo FF: Franchise Fee Factor: Franchise Fee Expense: True Up TRR: Reference: 38 FFU WS, L 5 39 * 0 39 +
Schedule 5 Return and Capitalization Calculation of Components of Cost of Capital Rate Cells shaded yellow are input cells Notes FERC Form Reference or Instruction Value RETURN AND CAPITALIZATION CALCULATIONS 3 5 7 8 9 0 Calculation of Long Term Debt Amount Bonds Account Less Reacquired Bonds Account Other Long Term Debt Account Unamortized Premium on Long Term Debt Account 5 Less Unamortized Discount on Long Term Debt Account Unamortized Debt Expenses Account 8 Unamortized Loss on Reacquired Debt Account 89 Composite Tax Rate After tax amount of Unamortized Loss on Reacquired Debt Removal of Long Term Debt Related to Fuel Inventories Adjustments related to "LT Debt Related to Fuel Inventories" Long Term Debt Amount 3 5 7 8 9 0 Calculation of Cost of LongTerm Debt Interest on LongTerm Debt Account 7 Amortization of Debt Discount and Expense Account 8 Amortization of Loss on Reacquired Debt Account 8. Less Amortization of Premium on Debt Account 9 Less Amort. of Gain on Reacquired Debt Account 9. Interest on Long Term Debt Related to Fuel Inventories Amortizations related to "LongTerm Debt Related to Fuel Inventories" Cost of Long Term Debt LongTerm Debt Cost Percentage 3 5 Calculation of Preferred Stock Amount Preferred Stock Amount Account 0 Unamortized Issuance Costs Net Gain (Loss) From Purchase and Tender Offers Preferred Stock Amount 7 8 9 Calculation of Cost of Preferred Stock Cost of Preferred Stock Account 37 Amortization of Net Gain (Loss) From Purchases and Tender Offers Amortization Issuance Costs Cost of Preferred Stock Account 37 30 Preferred Stock Cost Percentage 3 3 33 3 35 3 Calculation of Common Stock Equity Amount Proprietary Capital Less Preferred Stock Amount Account 0 Minus Net Gain (Loss) From Purchase and Tender Offers Less Unappropriated Undist. Sub. Earnings Acct.. Less Accumulated Other Comprehensive Loss Account 9 Common Stock Equity Amount 3month avg. 3month avg.; enter negative 3month avg. 3month avg. 3month avg.; enter negative 3month avg.; enter negative 3month avg.; enter negative 3month avg.; enter negative Enter negative Enter negative Enter negative ROR WS, ROR WS, ROR WS, 3 ROR WS, ROR WS, 5 ROR WS, ROR WS, 7 BaseTRR WS, 58 7 * ( 8) ROR WS, 0 ROR WS, L + L + L3 + L + L5 + L + L9 + L0 + L FF 7.c FF 7.3c FF 7.c FF 7.5c FF 7.c See Note See Note Sum of s 3 to 9 0 / 3month avg. 3month avg. 3month avg. ROR WS, ROR WS, 3 ROR WS, Sum of s to Enter positive FF 8.9c See Note 3 See Note Sum of s to 8 9 / 5 ROR WS, 3 ROR WS, See Note 5 ROR WS, 3 ROR WS, 35 Sum of s 3 to 35 3month average Same as L, but negative Same as L, but reverse sign 3month avg.; enter negative 3month avg., enter of FF Notes: ) Enter amount associated with bonds for which SCE has California Public Utilities Commission authority to utilize 00 for fuel inventories, amounts from SCE internal records. ) Enter amount associated with bonds for which SCE has California Public Utilities Commission authority to utilize 00 for fuel inventories, amounts from SCE internal records. 3) Annual amortization associated with events listed in note on ROR. ) Annual amortization associated with preferred equity issues listed in note on ROR. 5) Negative of, charge to common equity reversed for ratemaking.
Schedule 5 Return and Capitalization Calculation of 3 Average Capitalization Balances Item 3 Avg. = Sum (C to C)/3 3 5 7 0 3 3 3 35 Col February Bonds Account (Note ): Reacquired Bonds Account (Note ): Other Long Term Debt Account (Note 3): Unamortized Premium on Long Term Debt Account 5 (Note ): Unamortized Discount on Long Term Debt Account (Note 5): Unamortized Debt Expenses Account 8 (Note ): Unamortized Loss on Reacquired Debt Account 89 (Note 7): Long Term Debt Related to Fuel Inventories (Note 8): Adjustments related to "LT Debt Related to Fuel Inventories" (Note 9): Preferred Stock Amount Account 0 (Note 0): Unamortized Issuance Costs (Note ): Net Gain (Loss) From Purchase and Tender Offers Note ): Proprietary Capital (Note 3): Unappropriated Undist. Sub. Earnings Acct.. (Note ): Accumulated Other Comprehensive Loss Account 9 (Note 5): Col Col 7 Col 8 Issue Issuance Date 3 November Issuance Date Face Amount October Maturity Date CPUC Authority 9) Unamortized discount and expense for fuel inventory bonds on 0, amounts in columns from SCE internal records. 0) Amount in Column from FF.3c, amount in Column from FF.3d, amounts in columns 33 from SCE internal records. ) Amounts in columns are from SCE internal records. List associated securities, Face Amount, Issuance Date, Issuance Costs, Amortization Period: Issue September Notes: ) Amount in Column from FF.8c, amount in Column from FF.8d, amounts in columns 33 from SCE internal records. ) Amount in Column from FF.9c, amount in Column from FF.9d, amounts in columns 33 from SCE internal records. 3) Amount in Column from FF.c, amount in Column from FF.d, amounts in columns 33 from SCE internal records. ) Amount in Column from FF.c, amount in Column from FF.d, amounts in columns 33 from SCE internal records. 5) Amount in Column from FF.3c, amount in Column from FF.3d, amounts in columns 33 from SCE internal records. ) Amount in Column from FF.9c, amount in Column from FF.9d, amounts in columns 33 from SCE internal records. 7) Amount in Column from FF.8c, amount in Column from FF.8d, amounts in columns 33 from SCE internal records. 8) Enter amount of bonds for which SCE has California Public Utilities Commission authority to utilize 00 for fuel inventories. List qualifying bond issuances, Face Amount, Coupon Interest Rate, Issuance Date, Expiration Date, and CPUC authority: Coupon Interest Rate 0 Instructions: ) Enter 3 months of balances for capital structure for Prior and previous to Prior in Columns. Beginning and End of year amounts in Columns and are from FERC Form, as referenced in below notes. ) Enter information in Note 8 for any Fuel Inventory Bonds. SCE must have California Public Utilities Commission approval to utilize 00 of the proceeds of such Fuel Inventory Bonds only to finance fuel inventory. 3) Update notes and as necessary. Face Amount Col 9 Issuance Costs Amortization Period Notes
Schedule 5 Return and Capitalization ) Amounts in columns are from SCE internal records. List associated securities and event, Event Date, Amortization Amount, Amortization Period: Issue/Event Event Date Amortization Amount Amortization Period Notes 3) Amount in Column from FF.c, amount in Column from FF.d, amounts in columns 33 from SCE internal records. ) Amount in Column from FF.c, amount in Column from FF.d, amounts in columns 33 from SCE internal records. 5) Amount in Column from FF.5c, amount in Column from FF.5d, amounts in columns 33 from SCE internal records.
Schedule Plant In Service Plant In Service Inputs are shaded yellow ) Transmission Plant ISO Balances for Transmission Plant ISO during the Prior, including of previous year (See Note ): Prior 3 February 5 7 8 9 0 September October November 3 3Mo. Avg: 350. Col 350. 35 Col 353 35 35 0 357 358 Sum C C 359 Average: 355 Col 9 Balances for Distribution Plant ISO (See Note ) 7 Col 8 ) Distribution Plant ISO Prior 5 Col 7 30 Col 3 Sum C C 3
Schedule Plant In Service 3) ISO Transmission Plant ISO Transmission Plant is the sum of "Transmission Plant ISO" and "Distribution Plant ISO" Amount Average value: EOY Value: 8 9 Sum of, and 7, Sum of 3, and, ) General Plant + Electric Miscellaneous Intangible Plant ("G&I Plant) General and Intangible Plant is an allocated portion of G&I Plant based on the Trans. W&S Allocation Factor 0 Note Prior 3 a) BOY/EOY Average G&I Plant Average BOY/EOY Value: Transmission W&S Allocation Factor: General + Intangible Plant: General Plant Balances Data FF 0.99.b and 0.5b FF 07.99.g and 0.5g G&I Plant Balances Amount Average of 0 and. Allocators WS, 9 * 3. Amount. Allocators WS, 9 5 *. b) EOY G&I Plant 5 7 Intangible Plant Balances EOY Value: Transmission W&S Allocation Factor: General + Intangible Plant: Notes Beginning of year amount End of year amount Transmission Activity Used to Determine ly Transmission Plant ISO Balances ) Transmission Activity by Account (See Note 3) Col Col Col 7 Col 8 Col 9 0 Sum C C 8 9 30 3 3 33 3 35 3 37 38 39 Prior February September October November 0 : 350. 350. 35 353 35 355 35 357 358 359
Schedule Plant In Service ) Incentive Plant Activity (See Note ) Col Col Col 7 Col 8 Col 9 0 Sum C C 3 5 7 8 9 50 5 5 Prior February September October November 53 : 350. 350. 35 353 35 355 35 357 358 359 3) Transmission Activity Not Including Incentive Plant Activity (See Note 5): Col Col Col 7 Col 8 Col 9 0 Sum C C 5 55 5 57 58 59 0 3 5 Prior February September October November : 350. 350. 35 353 35 355 35 357 358 359
Schedule Plant In Service ) Calculation of change in NonIncentive ISO Plant: A) Change in ISO Plant Balance to (See Note ) 350. 7 350. 35 353 35 355 35 357 358 359 B) Change in Incentive ISO Plant (See Note 7) 350. 8 350. 35 353 35 355 35 357 358 359 C) Change in NonIncentive ISO Plant (See Note 8) 350. 9 350. 35 353 35 355 35 357 358 359 5) Other Transmission Activity without Incentive Plant Activity (See Note 9): Col Col Col 7 Col 8 Col 9 0 Sum C C 70 7 7 73 7 75 7 77 78 79 80 8 Prior February September October November 8 : 350. 350. 35 353 35 355 Notes: ) Amounts on must match Plant Study amounts for Transmission Plant ISO for previous year. Amounts on 3 must match amounts on PlantStudy WS for Transmission Plant ISO. Calculation of remaining amounts is sum of: a) Other Transmission Activity without Incentive Plant Activity (on s 70 to 8) b) Incentive Plant Activity (on s to 5) c) Previous month balance ) Amounts on 5 must match Plant Study amounts for Distribution Plant ISO for previous year. Amounts on must match amounts on PlantStudy WS for Distribution Plant ISO. 3) Includes recorded Transmission PlantInService additions, retirements, transfers and adjustments. ) Column matches 'Activity for Incentive Projects' on incentiveplant WS, s 39 to 5. 5) Amount in matrix on lines 8 to 39 minus amount in matrix on lines to 5 ) Amount on 3 less amount on for each account. 7) 53 8) Amount on 7 less amount on 8 for each account. 9) Amount in matrix on s 5 to 5 times ratio of amount on 9 to amount on for each account. 35 357 358 359
Schedule 7 Transmission Plant Study Summary Transmission Plant Study Input cells are shaded yellow A) Plant Classified as Transmission in FERC Form : 3 5 7 8 9 0 3 5 7 8 9 0 Plant Account Data Transmission Plant ISO ISO of Substation 35 353 Substation FF 07.9g FF 07.50g L3+L Land 350 FF 07.8g Substation and Land L5+L8 s 35 355 35 357 358 359 s FF 07.5g FF 07.5g FF 07.53g FF 07.5g FF 07.55g FF 07.5g Sum L3 to L8 Transmission L 0 + L 9 Notes Note B) Plant Classified as Distribution in FERC Form : 3 5 7 8 9 30 Plant Account Land: 30 Structures: 3 3 Structures Distribution Distribution Plant ISO Data ISO of FF 07.0g FF 07.g FF 07.g L + L 7 L + L 8 Notes: ) transmission does not include account 359. "Asset Retirement Costs for Transmission Plant" on this line is also equal to FF 07.58g ( Transmission Plant) less FF 07.57g (Asset Retirement Costs for Transmission Plant). ) Only accounts 303 included as there is no ISO plant in any other Distribution accounts. Instructions: ) Perform annual Transmission Study pursuant to instructions in tariff. ) Enter total amounts of plant from FERC Form in Column, " Plant". 3) Enter ISO portion of plant in Column, "Transmission Plant ISO, or Distribution Plant ISO". Note
Schedule 8 Accumulated Depreciation Accumulated Depreciation Reserve Input cells are shaded yellow ) Transmission Depreciation Reserve ISO Balances for Transmission Depreciation Reserve ISO during the Prior, including of previous year (See Note ): 3 5 7 8 9 0 3 Prior February September October November 3Mo. Avg: FERC Account: 350. Col 350. 35 Col 353 Col 7 35 Col 8 355 35 ) Distribution Depreciation Reserve ISO (See Note ) 5 7 FERC Account: 30 BOY: EOY: BOY/EOY Average: Col 3 =Sum C to C 3 Col 9 Average of 5 and 0 357 358 =Sum C to C 359
Schedule 8 Accumulated Depreciation 3) General and Intangible Depreciation Reserve General and Intangible Depreciation Reserve BOY: FF 9.8c for previous year EOY: FF 9.8c BOY/EOY Average: Average of 8 and 9 8 9 0 a) Average BOY/EOY General and Intangible Depreciation Reserve 3 G+I Dep. Reserve on Average BOY/EOY basis: Transmission W&S Allocation Factor: G + I Plant Dep. Reserve (BOY/EOY Average): Amount 0 Allocators WS, 9 * Amount 9 Allocators WS, 9 * 5 a) EOY General and Intangible Depreciation Reserve 5 G+I Dep. Reserve on Average EOY basis: Transmission W&S Allocation Factor: G + I Plant Dep. Reserve (EOY): Transmission Activity Used to Determine ly Transmission Depreciation Reserve ISO Balances ) Transmission Activity by Account (See Note 3) 7 8 9 30 3 3 33 3 35 3 37 38 39 Prior February September October November : 350. Col 350. 35 Col 353 Col 7 35 Col 8 355 Col 9 35 0 357 358 Sum C C 359 0
Schedule 8 Accumulated Depreciation ) Depreciation Expense (See Note ) 0 3 5 7 8 9 50 5 5 Prior February September October November : 350. Col 350. 35 Col 353 Col 7 35 Col 8 355 Col 9 35 0 357 358 Sum C C 359 3) Transmission Activity less Depreciation Expense (See Note 5) 53 5 55 5 57 58 59 0 3 5 Prior February September October November : 350. Col 350. 35 Col 353 Col 7 35 Col 8 355 Col 9 35 0 357 358 Sum C C 359
Schedule 8 Accumulated Depreciation ) Calculation of Other Transmission Activity A) Change in Depreciation Reserve ISO (See Note ) 350. 350. 35 353 35 355 35 357 358 359 B) Depreciation Expense (See Note 7) 350. 7 350. 35 353 35 355 35 357 358 359 C) Other Activity (See Note 8) 350. 8 350. 35 353 35 355 35 357 358 359 5) Other Transmission Activity (See Note 9) 9 70 7 7 73 7 75 7 77 78 79 80 8 Prior February September October November : 350. Col 350. 35 Col 353 Col 7 35 Col 8 355 Notes: ) Amounts on derived from Plant Study for previous year Prior. Amounts on 3 derived from Plant Study for Prior. Calculation of remaining amounts is sum of: a) Depreciation Expense (on s 0 to 5) b) Other Transmission Activity (on s 9 to 80) c) Previous month balance ) Amounts on 5 derived from Plant Study for previous year Prior. Amounts on derived from Plant Study for Prior. 3) Transmission Activity by Account represents accumulated depreciation changes for all Transmission plant. ) From Depreciation Worksheet, s to 35. 5) Amount in matrix on lines 7 to 38 minus amount in matrix on lines 0 to 5. ) 3. 7) 5. 8) 7. 9) Amount in matrix on s 53 to times ratio of amount on 8 to amount on 5 for each account. Col 9 35 0 357 358 Sum C C 359
Schedule 9 ADIT Accumulated Deferred Income Taxes Cells shaded yellow are input cells ) Summary of Accumulated Deferred Income Taxes a) End of Accumulated Deferred Income Taxes 3 5 7 8 9 0 3 5 Account Account 90 Account 8 Account 83 IRC Section 8(i)(9) Normalization Adjustment Accumulated Deferred Income Taxes ADIT 353, Col. 5, Col. 803, Col. 809, Col. 5 Sum of s to Previous Informational Filing, 5, Col. Average of 5 and 0 b) Beginning of Accumulated Deferred Income Taxes BOY ADIT Accumulated Deferred Income Taxes c) Average of Beginning and End of Accumulated Deferred Income Taxes Average ADIT Average BOY/EOY ADIT:
Schedule 9 ADIT ) Account 90 Detail 00 0 0 03 0 05 0 07 08 09 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 33 3 35 3 37 38 39 0 ACCT 90 Electric: END BAL per G/L DESCRIPTION Gas, Generation or Other Related Col ISO Only Plant Related Col Labor Related Col 7 Description
Schedule 9 ADIT Continuation of Account 90 Detail 3 5 7 8 9 50 5 5 53 5 55 5 57 58 59 0 3 5 7 8 9 70 7 7 73 7 75 50 ACCT 90 Electric: END BAL per G/L DESCRIPTION Electric 90 Gas, Generation or Other Related Col Col Col 7 ISO Only Plant Related Labor Related Description Sum of Above s beginning on 00
Schedule 9 ADIT Account 90 Gas and Other Income: 300 30 30 303 30 305 30 307 308 309 30 3 3 33 3 Account 90 Gas and Other Income 350 35 35 353 Account 90 Allocation Factors (Plant and Wages) Account 90 ADIT (Sum of amounts in Columns to ) 35 FERC Form Account 90 Col Must match amount on 35, Col. Col Col Col Col 7 Sum of Above s beginning on 300 50 + 350 Allocators WS s and 9 respectively. 35 * 35 for Cols 5 and. Col. 00 ISO. FF 3.8c 3) Account 8 Detail 00 0 0 03 0 05 0 07 08 09 0 3 5 7 8 9 0 ACCT 8 DESCRIPTION END BAL per G/L Gas, Generation or Other Related Col ISO Only Col Labor Related Plant Related Col 7 Description
Schedule 9 ADIT 50 5 5 Account 8 Allocation Factors (Plant and Wages) Account 8 ADIT (Sum of amounts in Columns to ) 53 FERC Form Account 8 Col Col Must match amount on 50, Col. Sum of Above s beginning on 00 Allocators WS s and 9 respectively. 50 * 5 for Cols 5 and. Col. 00 ISO. FF 75.5k ) Account 83 Detail 500 50 50 503 50 505 50 507 508 509 50 5 5 53 5 55 5 57 58 59 50 5 5 53 5 55 5 57 58 59 530 53 53 533 53 535 53 537 538 539 ACCT 83 Electric: END BAL per G/L DESCRIPTION Gas, Generation or Other Related Col ISO Only Plant Related Col Labor Related Col 7 Description
Schedule 9 ADIT Continuation of Account 83 Detail 50 5 5 53 5 55 5 57 58 59 550 55 55 553 55 555 55 557 558 559 50 5 5 53 5 55 5 57 58 59 ACCT 83 Electric (continued): 50 END BAL per G/L DESCRIPTION Electric 83 Gas, Generation or Other Related Col ISO Only Plant Related Col Labor Related Col 7 Description Sum of Above s beginning on 500 Acount 83 Gas and Other: 700 70 70 703 70 705 70 707 708 709 70 7 7 73 Col Col Col 7
Schedule 9 ADIT Account 83 Gas and Other 800 80 80 803 Account 83 Allocation Factors (Plant and Wages) Account 83 ADIT (Sum of amounts in Columns to ) 80 FERC Form Account 83 Col Col Must match amount on 80, Col. Sum of Above s beginning on 700 50 + 800 Allocators WS s and 9 respectively. 80 * 80 for Cols 5 and. Col. 00 ISO. FF 77.9k 5) Normalization Adjustment for Unused Bonus Depreciation END BAL per G/L ACCT IRC Section 8(i)(9) Normalization Adjustment 805 80 807 808 809 3 Federal Income Taxes Payable Interest Income Reclassification Remaining Amount of FIT Payable Plant Allocation Factor IRC Section 8(i)(9) Normalization Adjustment (In Column 5) Gas, Generation or Other Related Col ISO Only Plant Related Col Labor Related Col 7 Description FF 3.3i See Note See Note 805 + 80 See Note 3 807 * 808 for Column 5 Note : Only include if Federal Income Tax Account 3 payable in FF page 3 charged to Acct 09. or 08. in Column (i) is a negative amount (i.e., debit balance). Note : Adjustment to exclude interest component related portion of Federal Income Taxes Payable on 805. Note 3: Allocate "Remaining Amount of FIT Payable" based on Transmission Plant Allocation Factor Remaining Amount is Gas, Generation, or Other Related.
Schedule 0 CWIP Prior CWIP and Forecast Period Incremental CWIP by Project Prior CWIP is the amount of Construction Work In Progress for projects that have received Commission approval to include CWIP in Rate Base. 3 5 7 8 9 0 3 ) Prior CWIP, and by Project = Sum of all Prior columns ly CWIP February September October November 3 Averages: Tehachapi Col 7 5 7 8 9 0 3 5 7 8 Prior February September October November 3 Averages: Col Devers to Colorado River Eldorado Ivanpah Col 8 Colorado River Substation Expansion Whirlwind Substation Expansion Col 9 0 South of Kramer West of Devers LugoPisgah/ Col Red Bluff Project X Project Y
Schedule 0 CWIP ) Forecast Period CWIP, and by Project Forecast Period CWIP is the amount of CWIP in Rate Base expected for these projects. = Sum of all columns Forecast ly CWIP See Note 9 30 3 3 33 3 35 3 37 38 39 0 3 5 7 8 9 Forecast Period February September October November February September See Note 50 5 5 53 5 55 5 57 58 59 0 3 5 7 8 9 70 Forecast Period February September October November February September Tehachapi Col 7 Col Devers to Colorado River Eldorado Ivanpah Col 8 Colorado River Substation Expansion Whirlwind Substation Expansion 0 South of Kramer West of Devers Col LugoPisgah Col 9 Red Bluff Project X Project Y
Schedule 0 CWIP 3) Forecast Period Incremental CWIP, and by Project Forecast Period Incremental CWIP is the amount of CWIP in Rate Base expected for these projects, minus the Prior yearend amount. Equals amounts from s 99 and 5070 minus amount on s 3 and 7. Sum of all Cols Forecast Forecast ly Period Incremental CWIP February September October November February September 3 Averages: Col Devers to Colorado River Eldorado Ivanpah Col See Note 7 7 73 7 75 7 77 78 79 80 8 8 83 8 85 8 87 88 89 90 9 9 See Note 93 9 95 9 97 98 99 00 0 0 03 0 05 0 07 08 09 0 3 Col 7 Tehachapi Col 8 Colorado River Substation Expansion Col 9 LugoPisgah/ 0 Forecast Whirlwind Period Substation South of West of Expansion Kramer Devers February September October November February September 3 Averages: Notes: ) Forecast Period is October of year following the Prior through September of the next year. Red Bluff Project X Project Y Instructions: ) Enter recorded amounts of CWIP during Prior on s 3, 57 (including of year previous to Prior ). ) Enter forecast CWIP total balances for these projects on s 99, 5070. 3) If Commission approval is granted to include CWIP in Rate Base for additional projects, utilize Project X, Y, and Z columns. If additional projects receive approval, add additional columns in same format.
Schedule Plant Held for Future Use TRANSMISSION PLANT HELD FOR FUTURE USE Inputs are shaded yellow Transmission Plant Held for Future Use shall be amounts of Electric Plant Held for Future Use (account 05) intended to be placed under the Operational Control of the ISO, plus an allocated amount of any General Electric Plant Held for Future Use, with the allocation factor being the Transmission Wages and Salaries AF. Electric PHFU Beginning of Balance End of Balance FF page.7d Plant intended to be placed under the Operational Control of the ISO: Description a b c d e f g h Type of Plant Beginning of Balance Col End of Balance 3 5 : General Plant Held for Future Use Wages and Salaries AF: Portion for Transmission PHFU: Beginning of Balance End of Balance Sum of above lines FF page Allocators WS, L 9 L*L5 All other Electric Plant Held for Future Use not intended to be placed under the Operational Control of the ISO: 7 Transmission PHFU: 8 9 Average of BOY and EOY Transmission PHFU: Beginning of Balance End of Balance Beginning of Balance Note L3+L End of Balance Sum of 8 / Calculation of Gain or Loss on Transmission Plant Held for Future Use Land 0 Gain or Loss on Transmission Plant Held for Future Use Land SCE Records Instructions: ) For any Electric Plant Held for Future Use intended to be placed under the Operational Control of the ISO, list on lines a, b, etc. Provide description in Column. Note type of plant (land or other) in Column. Under "" (Column 5), state the line number on FERC Form page from which the amount is derived. BOY amount will be EOY value from previous year FERC Form, EOY amount will be in current year FF. ) For any Electric Plant Held for Future Use classified as General note amount on. 3) Add additional lines i, j, k, etc. as necessary to include additional projects intended to be placed under the Operational Control of the ISO. ) Gains and Losses on Transmission Plant Held for Future Use Land is treated in accordance with Commission policy. Any gain or loss on nonland portions of Transmission Plant Held for Future Use is not included. Notes: ) Amount of not intended to be placed under the Operational Control of the ISO.
Schedule Abandoned Plant Determination of amount of Abandoned Plant and Abandoned Plant Amortization Expense Input data is shaded yellow Initially Abandoned Plant Amortization Expense and Abandoned Plant are both zero. Upon Commission approval of recovery of abandoned plant costs for a specific project or projects, SCE will complete this worksheet in accordance with that Order. Abandoned Plant for each project represents the amount of costs that the Order approves for inclusion in Rate Base. Abandoned Plant Amortization Expense for each project represents the annual amortization of abandoned costs that the Order approves as an annual expense. Amount for Prior Note: Abandoned Plant Amortization Expense: Sum of projects below for PY. Abandoned Plant (BOY): Sum of projects below for PY. Sum of projects below for PY. 3 Abandoned Plant (EOY): Average of s and 3. Abandoned Plant (BOY/EOY Average): 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 First Project: Fill in Name 0 0 03 0 05 0 07 08 09 00 0 0 03 0 05 0 07 08 09 030 03 03 033 03 035 EOY Abandoned Plant Abandoned Plant Amort. Expense nd Project: Fill in Name EOY Abandoned Plant Abandoned Plant Amort. Expense 3rd Project: Fill in Name EOY Abandoned Plant Instructions: ) Upon Commission approval of recovery of abandoned plant costs for a project: a) Fill in the name the project in order (First Project, Second Project, Third Project, etc.). b) Fill in the table with annual End of ("EOY") Abandoned Plant and Abandoned Plant Amortization Expense amounts in Accordance with the Order. If table can not be filled out completely, fill out at least through the Prior at issue. c) Sum projectspecific amounts for each project and enter in lines,, and 3 for the Prior at issue. (BOY value is EOY value from previous year) ) Add additional projects if necessary in same format. 3) Add additional years past 035 if necessary. Abandoned Plant Amort. Expense
Schedule 3 Working Capital Calculation of Components of Working Capital Inputs are shaded yellow ) Calculation of Materials and Supplies Materials and Supplies is the amount of total Account 5 Materials and Supplies times the Transmission Wages and Salaries AF 3 Data FF 7.b FF 7.c Materials and Supplies Balances Notes Beginning of year ("BOY") amount End of ("EOY") amount Materials and Supplies EOY Value: Average BOY/EOY Value: * 3 * See Note, c See Note, f Average BOY/EOY Value Account 5: Transmission Wages and Salaries AF: 5 7 8 ) Calculation of Prepayments Prepayments is an allocated portion of Prepayments based on the Transmission Plant Allocation Factor. Data Prepayments Balances FF.57d FF.57c ( + ) / Allocators WS, 9 Notes a) BOY/EOY Average calculation Average BOY/EOY Value: ( 7 + 8) / Transmission Plant Allocation Factor: Allocators WS, Prepayments: 9 * 0 b) EOY calculation EOY Value: 8 3 Transmission Plant Allocation Factor: Allocators WS, Prepayments: * 3 Notes: ) Remove any amounts related to years prior to the effective date of the formula on b and e below. a) Beginning of Amount Prepayments Balances a FERC Form Acct. 5 Recorded Amount: FF.57d b Prior Period Adjustment: Note c BOY Prepayments Amount: ab 9 0 b) End of Amount d e f FERC Form Acct. 5 Recorded Amount: Prior Period Adjustment: BOY Prepayments Amount: Prepayments Balances FF.57c Note de
Schedule Incentive Plant Plant Balances For Incentive Projects Receiving either ROE Incentives ("Transmission Incentive Plant") or CWIP ("CWIP Plant") Input data is shaded yellow A) Summary of Incentive Project plant balances receiving ROE incentives ("Transmission Incentive Plant") and/or CWIP ("CWIP Plant") and calculation of balances needed to determine the following: ) Rate Base in Prior ) Prior Incentive Rate Base End of 3) Prior Incentive Rate Base 3 Average Transmission Incentive Project plant balances and CWIP Plant may affect the following: a) CWIP Plant during the Prior is included in Rate Base (used in Prior TRR and True Up TRR). b) Forecast Period Incremental CWIP contributes to Forecast Plant Additions c) CWIP Plant receiving an ROE adder contributes to Prior Incentive Rate Base EOY, or Prior Incentive Rate Base 3 Average as appropriate. d) "TIP Net Plant In Service" at EOY Prior is used to calculate the PY Incentive Rate Base (on EOY basis). e) "TIP Net Plant In Service" in PY is used to calculate the Prior Incentive Rate Base (on 3month average basis). 3 5 7 8 9 0 ) Summary of CWIP Plant in Prior and Forecast Period Prior Prior 3 Endof Average Incentive CWIP Plant CWIP Plant Project Amount Amount ) Tehachapi ) DeversColorado River 3) EldoradoIvanpah ) LugoPisgah 5) Red Bluff ) Whirlwind Substation Exp. 7) Colorado River Sub. Exp. 8) South of Kramer 9) West of Devers 0) s: Forecast Period Incremental CWIP 3 Avg. Amount Notes: CWIP WS s 3,, and 9 CWIP WS s 3,, and 9 CWIP WS s 3,, and 9 CWIP WS s 3,, and 9 CWIP WS s 3,, and 9 CWIP WS s 7, 8, and CWIP WS s 7, 8, and CWIP WS s 7, 8, and CWIP WS s 7, 8, and Add additional lines as appropriate ) Summary of Prior Incentive Rate Base amounts (EOY Values) = C + C3 Prior Incentive Rate Base 3 5 7 8 ) Rancho Vista ) Tehachapi 3) DeversColorado River ) PY Incentive Net Plant: EOY CWIP Portion EOY TIP Net Plant In Service Notes: 37, C, C, and 37, C, C, and 37, C3 Add additional lines as appropriate End of 3) Summary of Prior Incentive Rate Base amounts (3 Average values) 9 0 3 Incentive Project ) Rancho Vista ) Tehachapi 3) DeversColorado R ) PY Incentive Net Plant: = C + C3 Prior Incentive Rate Base 3 Avg. CWIP Portion 3 Avg. TIP Net Plant In Service Portion Notes: 38, C, C, and 38, C, C, and 38, C3 Add additional lines as appropriate 3 Average
Schedule Incentive Plant ) Prior TIP Net Plant In Service 5 7 8 9 30 3 3 33 3 35 3 37 38 Prior February September October November 3 Averages: TIP Net Plant In Service 39 0 3 5 7 8 9 50 5 5 Transmission Activity for Incentive Projects = C C Account 350359 Activity for Incentive Projects Account 303 Activity Col Devers to Colorado River Tehachapi 5) Transmission Activity for Incentive Projects Prior February September October November Rancho Vista Project X C: Sum of below projects for each month ) Calculation of Prior Net Plant in Service amounts for each Incentive Project a) Tehachapi 53 5 55 5 57 58 59 0 3 5 Prior February September October November = C C Plant InService Accumulated Depreciation Net Plant In Service Col = C Previous C Transmission Activity Notes of year previous to Prior
Schedule Incentive Plant b) Rancho Vista 7 8 9 70 7 7 73 7 75 7 77 78 Prior February September October November 79 80 8 8 83 8 85 8 87 88 89 90 9 9 93 9 95 9 97 98 99 00 0 0 03 0 = C C Plant InService Accumulated Depreciation Net Plant In Service = C C Plant InService Accumulated Depreciation Net Plant In Service d) Eldorado Ivanpah Prior February September October November c) Devers to Colorado River Prior February September October November = C C Plant InService Accumulated Depreciation Net Plant In Service Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity
Schedule Incentive Plant e) Lugo Pisgah 05 0 07 08 09 0 3 5 7 Prior February September October November 8 9 0 3 5 7 8 9 30 = C C Plant InService Accumulated Depreciation Net Plant In Service f) Red Bluff Prior February September October November = C C Plant InService Accumulated Depreciation Net Plant In Service Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity g) Whirlwind Substation Expansion 3 3 33 3 35 3 37 38 39 0 3 Prior February September October November Plant InService Accumulated Depreciation = C C Net Plant In Service
Schedule Incentive Plant 5 7 8 9 50 5 5 53 5 55 5 h) Colorado River Substation Expansion Prior Plant InService February September October November i) South of Kramer 57 58 59 0 3 5 7 8 9 Prior February September October November 70 7 7 73 7 75 7 77 78 79 80 8 8 Prior February September October November Accumulated Depreciation = C C Plant InService Accumulated Depreciation Net Plant In Service = C C Plant InService Accumulated Depreciation Net Plant In Service k) Project Z Add additional Incentive Projects as approved. Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity Col = C Previous C Transmission Activity = C C Net Plant In Service j) West of Devers
Schedule Incentive Plant ) Summary of Incentive Projects and incentives granted 83 8 85 A) Rancho Vista Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 8 87 88 B) Tehachapi Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: C) Devers to Colorado River Incentives Received: CWIP: ROE adder: Cite: Cite: ROE adder: 00 Abandoned Plant: 89 90 9 9 93 9 95 9 97 00 Abandoned Plant: D) Devers to Palo Verde Incentives Received: CWIP: 98 99 00 E) Eldorado Ivanpah Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 0 0 03 F) Lugo Pisgah Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 0 05 0 G) Red Bluff Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 07 08 09 H) Whirlwind Substation Expansion Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 0 I) Colorado River Substation Expansion Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 3 5 J) South of Kramer Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: 7 8 K) West of Devers Incentives Received: CWIP: ROE adder: 00 Abandoned Plant: Cite: Cite: 9 0 L) Future Incentive Projects CWIP: ROE adder: 00 Abandoned Plant: Instructions: ) Upon Commission approval of any incentives for additional projects, add additional projects and provide cite to the Commission decision.
Schedule 5 Incentive Adders Determination of Incentive Adders Components of the TRR Input data is shaded yellow Two Incentive Adders are calculated: a) The Prior Incentive Adder is a component of the Prior TRR. b) The True Up Incentive Adder is a component of the True Up TRR. ) Calculation of Incremental Return on Equity Factor The Incremental Return on Equity Factor is the incremental Prior TRR expressed per 00 basis points of ROE incentive, for each million dollars of Incentive Net Plant. It is calculated according to the following formula: IREF = CSCP * 0.0 * (/( CTR)) *,000,000 3 where: CSCP = Common Stock Capital Percentage CTR = Composite Tax Rate Value IREF = BaseTRR WS, L BaseTRR WS, L 58 Above formula ) Determination of multiplicative factors for use in calculating Incentive Adders: Multiplicative factors are used to calculate the Incentive Adders on an Transmission Incentive Project specific basis. Multiplicative factor for each project is the ratio of its ROE adder to. 5 7 8 ) Rancho Vista ) Tehachapi 3) Devers to Colorado Rive ) Multiplicative Factor ROE Adder IncentivePlant WS, L 8 IncentivePlant WS, L 87 IncentivePlant WS, L 90 3) Calculation of Prior Incentive Adder (EOY) ) Determine Prior Incentive Adder for each Incentive Project by multiplying the IREF, the Multiplicative Factor, and the million of Prior Incentive Rate Base. ) Sum projectspecific Incentive Adders to yield the total Prior Incentive Adder. 9 0 3 Prior Incentive Rate Base ) Rancho Vista ) Tehachapi 3) Devers to Colorado Rive ) Multiplicative Factor Prior Incentive Adder = Prior Incentive Adder IncentivePlant WS, L 3, Col. IncentivePlant WS, L, Col. IncentivePlant WS, L 5, Col. Sum of above PY Incentive Adders for each individual project ) Calculation of TrueUp Incentive Adder ) Determine True Up Incentive Adder for each Incentive Project by multiplying the IREF, the Multiplicative Factor, and the million of True Up Incentive Net Plant. ) Sum projectspecific Incentive Adders to yield the total True Up Incentive Adder. 5 7 8 9 0 TrueUp Incentive Net Plant ) Rancho Vista ) Tehachapi 3) Devers to Colorado Rive ) Multiplicative Factor TrueUp Incentive Adder = TrueUp Incentive Adder IncentivePlant WS, L 9, Col. IncentivePlant WS, L 0, Col. IncentivePlant WS, L, Col. Sum of above PY Incentive Adders for each individual project
Schedule 5 Incentive Adders 5) Calculation of ROE for PlantIn Service in the True Up TRR a) Transmission Incentive Plant Net Plant In Service 3 Incentive Project ) Rancho Vista ) Tehachapi 3) DeversColorado R ) 3 Avg. TIP Net Plant In Service IncentivePlant WS, L 9, Col. 3 IncentivePlant WS, L 0, Col. 3 IncentivePlant WS, L, Col. 3 Add additional lines as appropriate b) Calculation of ROE Adders on TIP Net Plant In Service 5 7 8 9 30 Incentive Project ) Rancho Vista ) Tehachapi 3) DeversColorado R ) AfterTax True Up Incentive Adder True Up Incentive Adder : See Note See Note See Note See Note c) Equity Portion of Plant In Service Rate Base 3 3 Rate Base: CWIP Portion of Rate Base: Amount 33 3 35 Plant In Service Rate Base: Equity percentage: Equity Portion of Plant In Service Rate Base: TUTRR WS, 7 TUTRR WS, 3 3 BaseTRR WS, 33 * 3 d) ROE for Plant In Service in the True Up TRR 3 37 38 39 Plant In Service ROE Adder Percentage: Base ROE (Including 50 basis point CAISO Participation Adder): ROE for Plant In Service in True Up TRR: 30 * 35 0.3 BaseTRR WS, 9 3 + 38 Instructions: ) If additional projects receive ROE adders, add to end of lists, and include in calculation of each Incentive Adder. Notes: ) Column : The True Up Incentive Adder for each Incentive Project equals the IREF on 3, times the applicable Multiplicative Factor on s 5 to 8, times the million of TIP Net Plant In Service on s to. Column : The After Tax True Up Incentive Adder is derived by multiplying the amounts in Column by ( CTR) (Where the CTR is on ).
Schedule Plant Additions Forecast Plant Additions for InService ISO Transmission Plant Yellow shaded cells are Input Data Forecast Plant Additions represents the total increase in ISO Transmission Net Plant, not including CWIP, during the Rate Effective Period, incremental to the yearend Prior amount. It is calculated on a 3 Average Basis during the Rate Effective Period. = C C 3 5 7 8 9 0 3 5 7 8 9 0 Forecast Period February September October November February September 3 Averages: Forecast Net Plant Additions Col Forecast Forecast Forecast Accumulated Low Voltage Depreciation Gross Plant Gross Plant on Gross Plant Additions Additions Additions 0 0 0 Forecast Plant Additions is amount on, Column.
Schedule 7 Depreciation Expense Depreciation Expense Input cells are shaded yellow ) Calculation of Depreciation Expense for Transmission Plant ISO Balances for Transmission Plant ISO during the Prior, including of previous year: 3 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 33 3 35 3 37 38 Prior FERC Account: 350. February September October November Col 350. 35 Col 353 350. 35 35 Col 9 35 355.53 357 35 3.8 0 358 357 3.50 359 358.5 359 3.87.5 See Note 353. Col 8 355 353 ly Depreciation Expense for Transmission Plant ISO by FERC Account: Prior FERC Account: 350. February September October November s: Col 7 35 Depreciation Rates (Percent per year) See "DepRates" worksheet. 350. 350. 35 0.00..57 : PlantInService worksheet, s 3. 35 355 35 357 358 359 Annual Depreciation Expense for Transmission Plant ISO: (equals sum of monthly amounts)
Schedule 7 Depreciation Expense 39 0 3 5 7 8 9 50 5 5 53 5 55 5 57 58 59 0 3 5 7 8 9 70 ) Calculation of Depreciation Expense for Distribution Plant ISO 30 Distribution Plant ISO BOY Distribution Plant ISO EOY Average BOY/EOY : 3 3 Depreciation Rates (Percent per year) See "DepRates" worksheet. 30 3.7 3.5 Depreciation Expense for Distribution Plant ISO 3.90 See Note 30 3 PlantInService WS 5. PlantInService WS. 3 is sum of Depreciation Expense for accounts 30, 3, and 3 3) Calculation of Depreciation Expense for General Plant and Intangible Plant General Plant Depreciation Expense Intangible Plant Depreciation Expense Sum of General and Intangible Depreciation Expense Transmission Wages and Salaries Allocation Factor General and Intangible Depreciation Expense FF 33.0f FF 33.f 58 + 59 Allocators WS, 9 0 * ) Depreciation Expense Depreciation Expense is the sum of: ) Depreciation Expense for Transmission Plant ISO ) Depreciation Expense for Distribution Plant ISO 3) General and Intangible Depreciation Expense Depreciation Expense: Amount 37, 53 7 + 8 + 9 Notes: ) Depreciation Expense for each account for each month is equal to the previous month balance of Transmission Plant ISO for that same account, times the ly Depreciation Rate for that account. ly rate = annual rate on 7 /. ) Depreciation Expense for each account is equal to the Average BOY/EOY value on times the Depreciation Rate on 8.
Schedule 8 Depreciation Rates Depreciation Rates ) Transmission Plant ISO FERC Account 350. Fee Land 350. Easements 3 5 7 8 9 0 35 353 35 355 35 357 358 359 Structures and Improvements Station Equipment Towers and Fixtures Poles and Fixtures Overhead Conductors and Devices Underground Conduit Underground Conductors and Devices Roads and Trails ) Distribution Plant ISO FERC Account 3 30 3 3 39 3) General Plant FERC Account 389 390 39. 39.5 39. 39. 39.3 39.7 39. 39. 39. 39. 39. 393 395 398 397 397 397 397 397 39 39. 39.5 39 0 3 5 ) Intangible Plant FERC Account 30 303 30 303 303 303 303 5 7 8 9 0 3 5 7 8 9 30 3 3 33 3 35 3 37 38 Description Description Land and Land Rights Structures and Improvements Station Equipment Description Land and Land Rights Structures and Improvements Office Furniture Office Equipment Duplicating Equipment Personal Computers Mainframe Computers PC Software DDSMS CPU & Processing DDSMS Controllers, Receivers, Comm. DDSMS Telemetering & System DDSMS Miscellaneous DDSMS Map Board Stores Equipment Laboratory Equipment Misc Power Plant Equipment Telecom System Equipment Netcomm Radio Assembly Microwave Equip. & Antenna Assembly Fiber Optic Communication Cables Telecom Infrastructure Transportation Equip. Garage & Shop Equip. Tools & Work Equip. Shop Power Oper Equip Description Hydro Relicensing Radio Frequency Other Intangibles Cap Soft 5yr Cap Soft 7yr Cap Soft 0yr Cap Soft 5yr Plant Less Salvage 0.00..8.9.3..07.5.8.5 Removal Cost 0.00 0.00 0.73 0.3.30.8.3 0.00.9 0.00 0.00..57..53 3.8 3.50.5 3.87.5 Plant Less Removal Salvage Cost.7 0.00.5 0.3.5 0.38.7 3.5.90 Plant Less Removal Salvage Cost.7 0.00.53 0.09 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00.9 0.00 0.00 0.00.7 0.00 5.00 0.00.00 0.00 5.00 0.00.7 0.00 5.00 0.00.9 0.00 0.00 0.00.7 0.00.9 0.0.57 0.0.9 0.00 0.00 0.00 0.00 0.00.7 0.00.7. 5.00 0.00 0.00 0.00 0.00 0.00.9 0.00.7 5.00.00 5.00.7 5.00.9 0.00.7.0..9 0.00 0.00.7 Plant Less Removal Salvage Cost 7.37 0.00.50 0.00 5.00 0.00 0.00 0.00.9 0.00 0.00 0.00.7 0.00 7.37.50 5.00 0.00.9 0.00.7
Schedule 9 Operations and Maintenance Operations and Maintenance Expenses Cells shaded yellow are input cells ) Determination of Adjusted Operations and Maintenance Expenses for each account (Note ) 3 5 7 8 9 0 3 5 7 8 9 0 3 5 7 8 9 30 3 3 33 3 35 3 37 38 39 0 3 5 7 8 9 50 5 5 Account/Work Activity Rev Transmission Accounts 50 Operations Engineering 50 Sylmar/Palo Verde 5.000 Load Dispatching 5.00 Load DispatchReliability 5.00 Load Dispatch Monitor and Operate Trans. System 5.00 Scheduling, System Control and Dispatch Services 5.500 Reliability, Planning and Standards Development 5 MOGS Station Expense 5 Operating Transmission Stations 5 Routine Testing and Inspection 5 Sylmar/Palo Verde 53 Inspect and Patrol 5 Underground Expense 55 Wheeling Costs 55 WAPA Transmission for Remote Service 55 Transmission for Four Corners 5 ISO/RSBA/TSP Balancing Accounts 5 Training/Other 5 NERC/CIP Compliance 5 Transmission Regulatory Policy 5 FERC Regulation & Contracts 5 Grid Contract Management 5 Sylmar/Palo Verde/Other General Functions 57 Rents 57 Morongo Lease 57 Eldorado 57 Sylmar/Palo Verde 58 Maintenance Supervision and Engineering 58 Sylmar/Palo Verde 59 Maintenance of Structures 59.00 Hardware 59.00 Software 59.300 Communication 59 Sylmar/Palo Verde 570 Maintenance of Power Transformers 570 Maintenance of Transmission Circuit Breakers 570 Maintenance of Transmission Voltage Equipment 570 Maintenance of Miscellaneous Transmission Equipment 570 Substation Work Order Related Expense 570 Sylmar/Palo Verde 57 Poles and Structures 57 Insulators and Conductors 57 Transmission Rights of Way 57 Transmission Work Order Related Expense 57 Sylmar/Palo Verde 57 Maintenance of Underground Transmission s 57 Sylmar/Palo Verde 573 Provision for Property Damage Expense to Trans. Fac. Transmission Results Sharing (Note 3) Transmission O&M = C3 + C Col Recorded O&M Expenses Labor NonLabor Col = C7 + C8 Reason Note Col 7 Col 8 Adjustments Labor Col 9 = C0 + C = C + C8 Adjusted Recorded O&M Expenses Labor NonLabor NonLabor 0 = C3 + C7
Schedule 9 Operations and Maintenance 53 5 55 5 57 58 59 0 3 5 7 8 9 = C3 + C Account/Work Activity Rev Distribution Accounts 58 Operation and Relay Protection of Distribution Substations 58 Testing and Inspecting Distribution Substation Equipment 590 Maintenance Supervision and Engineering 59 Maintenance of Structures 59 Maintenance of Distribution Transformers 59 Maintenance of Distribution Circuit Breakers 59 Maintenance of Distribution Voltage Control Equipment 59 Maintenance of Miscellaneous Distribution Equipment Accounts with no ISO Distribution Costs Distribution Results Sharing (Note 3) Distribution O&M Col Recorded O&M Expenses Labor NonLabor Note Col = C7 + C8 Reason E Transmission and Distribution O&M Transmission O&M Expenses in FERC Form : Distribution O&M Expenses in FERC Form : TDBU Results Sharing FF 3.b Must equal 5, Column. FF3.5b Must equal 3, Column. AandG WS, Note, g Col 7 Col 8 Adjustments Labor Col 9 = C0 + C 0 = C3 + C7 = C + C8 Adjusted Recorded O&M Expenses Labor NonLabor NonLabor
Schedule 9 Operations and Maintenance ) Determination of ISO Operations and Maintenance Expenses for each account (Note 5). 70 7 7 73 7 75 7 77 78 79 80 8 8 83 8 85 8 87 88 89 90 9 9 93 9 95 9 97 98 99 00 0 0 03 0 05 0 07 08 09 0 3 5 7 8 9 Account/Work Activity Rev Transmission Accounts 50 Operations Engineering 50 Sylmar/Palo Verde 5.000 Load Dispatching 5.00 Load DispatchReliability 5.00 Load Dispatch Monitor and Operate Trans. System 5.00 Scheduling, System Control and Dispatch Services 5.500 Reliability, Planning and Standards Development 5 MOGS Station Expense 5 Operating Transmission Stations 5 Routine Testing and Inspection 5 Sylmar/Palo Verde 53 Inspect and Patrol 5 Underground Expense 55 Wheeling Costs 55 WAPA Transmission for Remote Service 55 Transmission for Four Corners 5 ISO/RSBA/TSP Balancing Accounts 5 Training/Other 5 NERC/CIP Compliance 5 Transmission Regulatory Policy 5 FERC Regulation & Contracts 5 Grid Contract Management 5 Sylmar/Palo Verde/Other General Functions 57 Rents 57 Morongo Lease 57 Eldorado 57 Sylmar/Palo Verde 58 Maintenance Supervision and Engineering 58 Sylmar/Palo Verde 59 Maintenance of Structures 59.00 Hardware 59.00 Software 59.300 Communication 59 Sylmar/Palo Verde 570 Maintenance of Power Transformers 570 Maintenance of Transmission Circuit Breakers 570 Maintenance of Transmission Voltage Equipment 570 Maintenance of Miscellaneous Transmission Equipment 570 Substation Work Order Related Expense 570 Sylmar/Palo Verde 57 Poles and Structures 57 Insulators and Conductors 57 Transmission Rights of Way 57 Transmission Work Order Related Expense 57 Sylmar/Palo Verde 57 Maintenance of Underground Transmission s 57 Sylmar/Palo Verde 573 Provision for Property Damage Expense to Trans. Fac. Transmission Results Sharing (Note ) 0 Transmission ISO O&M Col From C9 above From C0 above From C above Note Col = C7 + C8 Adjusted Recorded O&M Expenses Labor NonLabor Percent ISO Col 7 = C3 * C5 Col 8 = C * C5 ISO O&M Expenses Labor NonLabor 3,53,,995,0 3535.87 995.0595
Schedule 9 Operations and Maintenance Col From C9 above From C0 above From C above Note Col = C7 + C8 Adjusted Recorded O&M Expenses Labor NonLabor Percent ISO Account/Work Activity Rev Distribution Accounts 58 Operation and Relay Protection of Distribution Substations 58 Testing and Inspecting Distribution Substation Equipment 590 Maintenance Supervision and Engineering 59 Maintenance of Structures 59 Maintenance of Distribution Transformers 59 Maintenance of Distribution Circuit Breakers 59 Maintenance of Distribution Voltage Control Equipment 59 Maintenance of Miscellaneous Distribution Equipment Accounts with no ISO Distribution Costs Distribution Results Sharing (Note ) Distribution ISO O&M 3 5 7 8 9 30 3 3 33 3 35 ISO O&M Expenses (in Column ) 3 0 + 3 Col 7 = C3 * C5 Col 8 = C * C5 ISO O&M Expenses Labor NonLabor Notes: ) "Adjusted Operations and Maintenance Expenses for each account" are the total amounts of O&M costs booked to each Transmission or Distribution account, less adjustments as noted. ) Reasons for excluded amounts: 3) TDBU Results Sharing is allocated to Transmission and Distribution in proportion to labor in the respective functions. Transmission Results Sharing equals TDBU Results Sharing times the Transmission Results Sharing Percentage calculated below. Distribution Results Sharing equals TDBU Results Sharing times the Distribution Results Sharing Percentage below. TDBU Results Sharing is on : Transmission Results Sharing Percentage: Distribution Results Sharing Percentage: Percentage Calculation 5, / 5, 3, / 5, ) Results Sharing attributable to ISO Transmission is calculated as total Transmission Results Sharing in Column times the ratio of the total ISO O&M Labor Expenses in Column 8 to the total Labor expenses in Column. No Distribution Results Sharing is allocated to ISO Transmission. 5) "ISO Operations and Maintenance Expenses" is the amount of costs in each Transmission or Distribution account related to ISO Transmission Facilities. ) "Percent ISO" percentages are calculated in accordance with the method set forth in SCE's TO Tariff protocols.
Schedule 0 Administrative and General Expenses Calculation of Administrative and General Expense 3 5 7 8 9 0 3 5 Acct. 90 9 9 93 9 95 9 97 98 99 930. 930. 93 935 FERC Form Amount Description A&G Salaries Office Supplies and Expenses A&G Expenses Transferred Outside Services Employed Property Insurance Injuries and Damages Employee Pensions and Benefits Franchise Requirements Regulatory Commission Expenses Duplicate Charges General Advertising Expense Miscellaneous General Expense Rents Maintenance of General Plant Inputs are shaded yellow See Note Data Amount Excluded FF 33.8b FF 33.8b FF 33.83b FF 33.8b FF 33.85b FF 33.8b FF 33.87b FF 33.88b FF 33.89b FF 33.90b FF 33.9b FF 33.9b FF 33.93b FF 33.9b A&G Expenses: Amount 7 Remaining A&G after exclusions & Results Sharing Adjustment: Less Account 9: 7 Allocators WS, 9 8 * 9 Allocators WS, 5 Col * 3 Administrative and General Expenses: 0 + 5 7 8 9 30 3 3 33 3 35 3 37 Shareholder or Other Exclusions Amount Excluded (Sum of to Col ) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Franchise Requirements Col Results Sharing Notes 5 5 Amount to apply the Transmission W&S AF: Transmission Wages and Salaries Allocation Factor: Transmission W&S AF Portion of A&G: Transmission Plant Allocation Factor: Property Insurance portion of A&G: Acct. 90 9 9 93 9 95 9 97 98 99 930. 930. 93 935 A&G Expense 8 9 0 Note : Itemization of exclusions Col PBOPs Notes See Note See Note 3 See Note
Schedule 0 Administrative and General Expenses Note : Results Sharing Adjustment Adjust Results Sharing by excluding accrued Results Sharing Amount and replacing with the actual A&G Results Sharing payout. Amount a b Accrued Results Sharing Amount: Actual A&G Results Sharing payout: c d e f g Adjustment: Actual Results Sharing Payouts: Department A&G Customer Service Business Unit Power Production Business Unit Trans. And Dist. Business Unit Amount : Note Note, d Note Note Note Note Sum of d to g Note 3: PBOPs Exclusion Calculation a b c Authorized PBOPs expense amount: Prior FF PBOPs expense: PBOPs Expense Exclusion: Amount Note: 5,707,000 See instruction # See instruction # ba Note : Amount in 3, column equals amount in 8, column because all Franchise Requirements Expenses are excluded Franchise Fees Expenses component of the Prior TRR are based on Franchise Fee Factors. Instructions: ) Enter amounts of A&G expenses from FERC Form in s to. ) Fill out "Itemization of Exclusions" table for all input cells. Results Sharing amount in Column 3, is calculated in Note. The PBOPs exclusion in Column, is calculated in Note 3. a) Exclude amount of any Shareholder Adjustments, costs incurred on behalf of SCE shareholders, from relevant account in Column. b) Exclude entire amount of account 97 "Franchise Requirements" in Column, as those costs are recovered through the Franchise Fees Expense item. c) Exclude any amount of Account 930. "General Advertising Expense" not related to advertising for safety, siting, or informational purposes in column. d) Exclude all of Account 930. "Miscellaneous General Expense" in Column. 3) Results Sharing adjustment in Column 3 is made by determining the difference between the total accrued Results Sharing amount included in the FERC Form recorded cost amounts and the actual A&G Results Sharing payout (see note ). ) Determine the PBOPs exclusion. The authorized amount of PBOPs expense (line ) may only be revised pursuant to Commission acceptance of an SCE FPA Section 05 filing to revise the authorized PBOPs expense, in accordance with the tariff protocols. Accordingly, any amount different than the authorized PBOPs expense is excluded from account 9 (see note 3).
Schedule Revenue Credits A a b c FERC ACCT 50 50 50 B ACCT 90 95 90 C ACCT DESCRIPTION Late Payment Charge Comm. & Ind. Residential Late Payment NonResidential Late Payment D E DOLLARS Category F G H ISO I NonISO J A/P K L M Other Ratemaking Incremental N Threshold [0] 3 50 FF for Acct 50 Forfeited Discounts, p300.b (Must Equal ) a b c d e f g h i 5 5 5 5 5 5 5 5 5 Other Ratemaking 5 5 FF for Acct 5 Misc. Service Revenues, p300.7b (Must Equal 5) 7a 7b 7c 53 53 53 8 53 FF for Acct 53 Sales of Water and Power, p300.8b (Must Equal 8) 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 Other Ratemaking Other Ratemaking 9 0a 0b 0c 0d 0e 0f 0g 0h 0i 0j 0k 0l 0m 0n 0o 0p 0q 0r 0s 0t 0u 0v 0w 80 85 90 95 95 930 90 950 990 830 835 80 8 8 8 88 80 850 85 85 85 858 880 885 880 885 90 95 90 930 935 055 8700 Recover Unauthorized Use/NonEnergy Miscellaneous Service Revenue Ownership Cost Miscellaneous Service Revenues Returned Check Charges Service Reconnection Charges Service Establishment Charge Field Collection Charges Quickcheck Revenue PUC Reimbursement FeeElect Sales of Water & Water Power San Joaquin Sales of Water & Water Power Headwater Miscellaneous Adjustments Joint Pole Tariffed Conduit Rental Joint Pole Tariffed Pole Rental Cable Cos. Joint Pole Tariffed Process & Eng Fees Cable Joint Pole Tariffed Process & Eng Fees Conduit Joint Pole Pl Attchmnt Audit Undoc P&E Fee Joint Pole Aud Unauth Penalty Joint Pole NonTariffed Pole Rental Joint Pole NonTariff Process & Engineering Fees Joint Pole NonTariff Requests for Information Oil And Gas Royalties Def Operating Land & Facilities Rent Rev Facility Cost EIX/Nonutility Facility Cost Utility Rent Billed to NonUtility Affiliates Rent Billed to Utility Affiliates Meter Leasing Revenue Company Financed Added Facilities Company Financed Interconnect Facilities SCE Financed Added Faclty Interconnect Facility Finance Charge Operating Land & Facilities Rent Revenue Nonoperating Misc Land & Facilities Rent Miscellaneous Adjustments 5 FF for Acct 5 Rent from Elec. Property, p300.9b (Must Equal ) P P P P P P Notes 3 3 3, 7, 7 8
Schedule Revenue Credits a b c d c d e f g h i j k l m n o p q r s t u v w x y z aa bb cc dd ee ff gg hh ii jj kk ll mm nn oo pp qq rr ss tt uu vv ww xx yy zz 3 A B FERC ACCT C ACCT ACCT DESCRIPTION 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 8 88 80 8 8 88 830 8 850 855 8 8 8 88 870 89 85 85 858 850 85 858 8530 853 8538 87 878 870 87 8730 885 890 89 89 89 898 890 89 887 887 8888 905 95 958 9 9 97 97 97 978 98 988 055 Energy Related Services Distribution Miscellaneous Electric Revenues Added Facilities One Time Charge Building Rental Nev Power/Mohave Cr Service Fee Optimal Bill Prd Miscellaneous Revenues Tule Power Plant Revenue Microwave Agreement Utility Subs Labor Markup Non Utility Subs Labor Markup Reliant Eng FSA Ann PymntMandalay Reliant Eng FSA Ann PymntOrmond Beach Reliant Eng FSA Ann PymntEtiwanda Reliant Eng FSA Ann PymntEllwood Reliant Eng FSA Ann PymntCoolwater Property License Fee revenue Revenue From Recreation, Fish & Wildlife Mapping Services Enhanced Pump Test Revenue RTTC Revenue Revenue From Scrap Paper General Office CTAC Revenues AGTAC Revenues Other Inc/erd Party DCESM 3rd PartyDiv TmgCr PPD training ADT Vendor Service Revenue Read Water Meters Irvine Ranch Read Water Meters Rancho California Read Water Meters Long Beach SSID Transformer Repair Services Revenue Employee Transfer/Affiliate Fee ITCC/CIAC Revenues Revenue From Decomission Trust Fund Revenue From Decomissioning Trust FAS5 Offset to Revenue from NDT Earnings/Realized Offset to Revenue from FAS 5 FMV Revenue From Decomissioning Trust FAS5 Offset to Revenue from FAS 5 Gains & Loss Power Supply Installations IMS Consulting Fees IMS FTR Auction Revenue DA Revenue Direct Access ly Customer Charges EDBL Customer Finance Added Facilities SCE Energy Manager Fee Based Services SCE Energy Manager Fee Based Services Adj Off Grid Photo Voltaic Revenues Scheduling/Dispatch Revenues Interconnect Facilities ChargesCustomer Financed Interconnect Facilities Charges SCE Financed DMS Service Fees CCA Information Fees Operating Miscellaneous Land & Facilitie Miscellaneous Adjustments 5 FF for Acct 5 Other electric Revenues, p300.b (Must Equal 3) D E DOLLARS F Category Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking G H ISO I NonISO J A/P P P P P P P P P P A A A A A A A P K L Threshold [0] M Other Ratemaking Incremental N Notes 3 3 7,
Schedule Revenue Credits A B FERC ACCT ACCT ACCT DESCRIPTION 5a 5b 5c 5d 5e 5f 5g 5h 5i 5j 5k 5l 5m 5n 5o 5p 5q 5r 5s 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 5. 88 88 88 888 888 888 980 98 98 985 98 988 980 98 98 98 988 9830 9890 Trans of Elec of Others Pasadena FTS PPU/NonISO FTS NonPPU/NonISO ISOWheeling Revenue Low Voltage ISOWheeling Revenue High Voltage ISOCongestion Revenue Transmission of Elec of Others WDAT Radial RevBase Cost Reliant Coolwater High Voltage Trans Access Rev (Existing Contracts) Radial RevBase Cost Reliant Ormond Beach Radial RevO&M AES Huntington Beach Radial RevO&M Reliant Mandalay Radial RevO&M Reliant Coolwater Radial RevO&M Ormond Beach High Desert Tie Rental Rev Scheduling/Dispatch Revenues (CSS) Inland Empire CRT Tie EX Reliability Service Revenue NonPTO's 7 C 5. FF for Account 5. Revenues from Trans. Of Electricity of Others, p300.b (Must Equal ) D E DOLLARS F Category H ISO I NonISO J A/P K L Threshold [0] M Other Ratemaking Incremental N Notes Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking Other Ratemaking G 5 5 8a 9 0 57. FF for Account 57. Regional Control Service Revenues, p300.3b (Must Equal 9) 57. FF for Account 57. Miscellaneous Revenues, p300.b (Must Equal ) 0 a 3 a b c d e f g h i j k l m n o 5 7 Edison Carrier Solutions (ECS) 7 8335 ECS Pass Pole Attachments 7 8330 ECS Distribution Facilities 7 80 ECS Dark Fiber 7 85 ECS SCE Net Fiber 7 80 ECS Transmission Right of Way 7 835 ECS Wholesale FCC 7 80 ECS Infrstructure Leasing 7 85 ECS EU FCC Rev 7 85 ECS Cell Site Rent and Use (Active) 7 830 ECS Cell Site Reimbursable (Active) 7 830 ECS Communication Sites 7 830 ECS Cell Site Rent and Use (Passive) 7 835 ECS Cell Site Reimbursable (Passive) 7 835 ECS Micro Cell 7 80 ECS End User Universal Service Fund Fee 7 ECS 7 Other FF for Account 7 Revenues From Nonutility Operations p7.33c (Must Equal 5 + ) 0 P P A A A A A A A A P P P P A
Schedule Revenue Credits A B FERC ACCT ACCT 8a 8b 8c 8d 8e Subsidiaries 8. 8. 8. 8. 8. 9 30 3 C ACCT DESCRIPTION ESI (Gross Revenues Active) ESI (Gross Revenues Passive) Southern States Realty Mono Power Company SCE Capital Company 8. Subsidiaries 8. Other FF for Account 8. Equity in Earnings of Subsidiary Companies, p7.3c (Must Equal 9 + 30) 3 s 33 3 35 3 37 38 39 0 3 D E F DOLLARS Category Revenue Credits: 357890 35 = Sum Active categories in column L = 37D * 0 = Sum Passive categories in column L = 39D * 30 = 38D + 0D see Note = D * D = 35D * 3D Calculation Sum of Column D, and Column G, 3 Notes: CPUC Jurisdictional service related. Subject to sharing per the Gross Revenue Sharing Mechanism (). On an annual basis, once SCE obtains,7,389.55 (Threshold Gross Revenue) in NTP&S Revenues, any additional revenues (Incremental Gross Revenues) that SCE receives are shared between shareholders and ratepayers. For categories deemed Active, the Imcremental Gross Revenues are shared 90/0 between shareholders and ratepayers. For those categories deemed Passive, the Incremental Gross Revenues are shared 70/30 between shareholders and ratepayers. Generation related. NonISO facilities related. ISO transmission system related. Subject to balancing account treatment Allocated based on the currently approved CPUC GRC allocator. ISO Allocator = ISO portion of relates to monthly revenues received from customers for facilities that are part of the ISO network. Edison ESI is a subsidiary company. Gross revenues are not reported in FF, only net earnings. Net Earnings for ESI are reported on Acct 8., pg 5.5e. The first,7,389 million in gross revenues generated by activities are automatically classified as Threshold Revenue. Allocator is equal to the jurisdictional split of the Threshold Revenue, which is jurisdictionalized as 5.5M to FERC ratepayers and.m to CPUC ratepayers per the 009 CPUC General Rate Case. The ISO ratepayers' share of ratepayer revenue is 5.5M/.7M = 3.5. Allocated based on the currently approved CPUC Base Revenue Requirement Balancing Account (BRRBA) allocator. ISO portion of revenue is treated as. ISO Allocator = Mono Power Company is a subsidiary company. Net Earnings are reported on Acct 8., pg 5.e SCE Capital Company is a subsidiary company. Net Earnings are reported on Acct 8., pg 5.3e Southern States Realty is a subsidiary company. Gross revenues are not reported in FF, only net earnings. Net Earnings for ESI are reported on Acct 8., pg 5.7e. A/P Active Incremental Revenue Ratepayers' Share of Active Incremental Revenue Passive Incremental Revenue Ratepayers' Share of Passive Incremental Revenue Ratepayers' Share of Incremental Revenue ISO Ratepayers' Share of Incremental Revenue () ISO Ratepayers' Share of Incremental Revenue ISO Ratepayers' Share of NTP&S Gross Revenue NonISO 3.5 J I Ratepayers' Share of Threshold Revenue ISO Ratepayers' Share of Threshold Revenue () ISO Ratepayers' Share of Threshold Revenue 3.5 ISO H Calculation = 3K see Note = 33D * 3D Amount 5 G A P P K Threshold [0] L M Other Ratemaking N Incremental Notes,9,9, 5, 3,
Schedule Network Upgrade Credits and Interest Expense NETWORK UPGRADE CREDIT AND INTEREST EXPENSE ) Beginning of Balances: (Note ) 3 Notes Balance Outstanding Network Upgrade Credits Recorded in FERC Acct 5 Acct 5 Other Acct 5 See Note SCE Records + (Must equal 3) FF 3.5d ) End of Balances: (Note ) 5 7 8 Outstanding Network Upgrade Credits Recorded in FERC Acct 5 Acct 5 Other Acct 5 (Must equal 7) See Note 3 9 Average Outstanding Network Upgrade Credits Beginning and End of ( + 5) / 0 3 Interest On Network Upgrade Credits Recorded in FERC Acct Acct Other Acct (Must equal ) See Note SCE Records 0 + FF 3.8c SCE Records 5 + FF 3.5c Notes: Beginning of Balances are from of the year previous to the Prior. End of Balances are from of the Prior. 3 Only projects that are in Rate Base in the year reported are included. Interest relates to refund of facility and onetime payments by generator. For facility costs, preinservice date interest is excluded. For onetime costs, preinservice and postinservice interest is included.
Schedule 3 Regulatory Assets and Liabilities Determination of Regulatory Assets/Liabilities and Regulatory Debits 3 5 7 8 9 0 3 5 7 8 9 0 Other Regulatory Assets/Liabilities are a component of Rate Base representing costs that are created resulting from the ratemaking actions of regulatory agencies, not includable in other accounts. Pursuant to the Commission's Uniform System of Accounts, they are booked to account 8.3. SCE shall include a nonzero amount of Other Regulatory Assets/Liabilities only with Commission approval received subsequent to an SCE Section 05 filing requesting such treatment. Regulatory Debits are amounts approved for recovery in this formula transmission rate representing the approved annual recovery of Other Regulatory Assets/Liabilities as an expense item in the Base TRR, consistent with a Commission Order. Prior Amount Other Regulatory Assets/Liabilities (EOY): Other Regulatory Assets/Liabilities (BOY/EOY average): Regulatory Debits: Description of Issue Resulting in Other Regulatory Asset/Liability Issue # Issue # Issue #3 s: () Prior BOY Other Reg Asset/Liability () Prior EOY Other Reg Asset/Liability Calculation Sum of Column below Avg. of L 0, C and C 0, C3 Sum of above (3) Prior Regulatory Debit Instructions: ) Upon Commission approval of recovery of Other Regulatory Assets/Liabilities or Regulatory Debits costs through this formula transmission rate: a) Fill in Description for issue in above table. b) Enter costs in columns 3 in above table for the applicable Prior. ) Add additional lines as necessary for additional issues.
Schedule CWIP TRR Calculation of the Contribution of CWIP to the Base TRR ) CWIP Contribution to the Prior TRR and True Up TRR a) CWIP Balances: 3 5 7 8 9 0 Project Prior EOY Prior Average Forecast Period Amount Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: Amount EOY b) Return: CWIP Amount: Cost of Capital Rate: Cost of Capital: CWIP WS, s 3,, 9 CWIP WS, s 3,, 9 CWIP WS, s 3,, 9 CWIP WS, s 3,, 9 CWIP WS, s 3,, 9 CWIP WS, s 7, 8, CWIP WS, s 7, 8, CWIP WS, s 7, 8, CWIP WS, s 7, 8, CWIP WS, s 7, 8, CWIP WS, s 7, 8, Sum of s to Average Amount 3 5 Amount Amount BaseTRR WS, 53 3 * c) Income Taxes EOY Average Amount 7 8 9 0 3 CWIP Amount: Equity ROR w Preferred Stock ("ER"): Composite Tax Rate: Income Taxes: Amount BaseTRR WS, 5 BaseTRR WS, 58 Formula below Income Taxes = [(RB * ER) * (CTR/( CTR)] (No "Credits and Other Term", as Credits and Other is not related to CWIP) d) ROE Incentives: Value IREF = IncentiveAdder WS, 3 ) Tehachapi EOY Average Amount 5 7 Tehachapi CWIP Amount: ROE Adder : ROE Adder : Amount IncentiveAdder WS, 5 Below formula ) Devers to Colorado River EOY Average Amount 8 9 30 3 3 DCR EOY CWIP: ROE Adder : ROE Adder : Amount IncentiveAdder WS, Below formula ROE Adder = (CWIP/,000,000) * IREF * (ROE Adder/) e) of Return, Income Taxes, and ROE Incentives contribution to PYTRR and True Up TRR True Up TRR PYTRR Amount 33 3 35 3 37 38 Return: Income Taxes: ROE Adder Tehachapi: ROE Adder DCR: FF&U: : Amount 5 9 7 30 Note Sum s 33 to 37
Schedule CWIP TRR f) Contribution from each Project to the Prior TRR and True Up TRR ) Contribution to the Prior TRR Project 39 0 3 5 7 8 9 50 Cost of Capital Income Taxes Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: Col ROE Adder FF&U = Sum C to C Note Note Note Note Note Note Note Note Note Note Note Sum L 39 to L 9 ) Contribution to the True Up TRR Project 5 5 53 5 55 5 57 58 59 0 Cost of Capital Income Taxes Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: Col ROE Adder FF = Sum C to C ) Contribution from the Incremental Forecast Period TRR a) of all CWIP projects Value 3 5 7 Forecast Period Incremental CWIP: AFCRCWIP: CWIP component of IFPTRR without FF&U: FF&U: CWIP component of IFPTRR including FF&U:, IFPTRR WS, 3 * 5 * (FF + U Factors from FFU WS) 5 + Note Note Note Note Note Note Note Note Note Note Note Sum of s 8 to 78 b) Individual Project Contribution Amount wo FF&U Project 8 9 70 7 7 73 7 75 7 77 78 79 Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: Amount with FF&U Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Note 3 Sum of L 5 to
Schedule CWIP TRR 3) Contribution of CWIP to the Retail and Wholesale Base TRRs: a) of all CWIP projects Value 80 8 8 83 8 85 8 87 88 PY Return, Taxes, Incentive: CWIP component of IFPTRR wo FF&U: without FF&U: FF Factor: U Factor: Franchise Fees Amount: Uncollectibles Amount: Contribution of CWIP to Retail Base TRR: Contribution of CWIP to Wholesale Base TRR: Sum 33 to 3 5 80 + 8 FFU WS, 5 FFU WS, 5 8 * 83 8 * 8 8 + 85 + 8 8 + 85 b) Individual CWIP Project Contribution to the Retail Base TRR PYTRR IFPTRR wo FF&U 89 90 9 9 93 9 95 9 97 98 99 00 Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: wo FF&U Col FF&U Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 Note 5 c) Individual CWIP Project Contribution to the Wholesale Base TRR PYTRR wo FF&U 0 0 03 0 05 0 07 08 09 0 Tehachapi: Devers to Colorado River: Eldorado Ivanpah: LugoPisgah: Red Bluff: Whirlwind Sub Expansion: Colorado River Sub Expansion: South of Kramer: West of Devers: s: IFPTRR wo FF&U Col FF Note Note Note Note Note Note Note Note Note Note Note Notes: ) (Sum s 33 to 3) * (FF + U Factors from FFU WS) for Prior TRR (Sum s 3 to 37) * (FF Factor from FFU WS) for True Up TRR ) Project Cost of capital is a fraction of total Cost of Capital on 5 based on fraction of project CWIP Balances on s to,. Project Income Taxes is a fraction of total Income on 9 based on fraction of project CWIP Balances on s to,. ROE Adder is from s 35 and 3. FF&U Expenses are based on FF&U Factors on FFU worksheet. 3) Project Cost of capital is a fraction of total Cost of Capital on 5 based on fraction of project CWIP Balances on s to,. Project Income Taxes is a fraction of total Income on 9 based on fraction of project CWIP Balances on s to,. ROE Adder is from s 35 and 3. FF Expenses is based on FF Factor on FFU worksheet. ) Project contribution to total IFPTRR is based on fraction of Forecast Period CWIP Balances on s to,. 5) Column is from s 39 to 9, Sum of Column 3 (no FF&U). Column is from s 8 to 78 (no FF&U). Column 3 is sum of FF and U factors times sum of Columns and ) Same as Note 5 except no Uncollectibles Expense in Column 3.
Schedule 5 Wholesale Differences to Base TRR Calculation of Wholesale Difference to the Base TRR Inputs are shaded yellow The Wholesale Difference to the Base TRR represents the amount by which the Wholesale Base TRR differs as compared to the Retail Base TRR. This difference is attributable to differences in the following five items. These five items may affect the Base TRR by affecting Rate Base, or affecting an annual expense (amortization). If the annual amortization affects Income Taxes, there is an additional annual Income Tax Effect. The table summarizes these impacts for each item: Expense 3 5 a) Depreciation b) Taxes Deferred Make Up Adjustment (South Georgia) c) Excess Deferred Taxes d) Taxes Deferred Acct. 8 ACRS/MACRS e) Uncollectibles Expense Rate Base Difference Yes Yes Yes Yes No (Amortization) Expense Tax Impact No Yes Yes No No Difference Yes Yes Yes Yes Yes ) Calculation of Wholesale Rate Base Difference and Wholesale Rate Base Adjustment 7 8 9 0 a) Quantification of the Initial 00 Wholesale Rate Base Difference and annual change The difference between Retail and Wholesale Rate Base is attributable to the following four items, with with the Initial Prior 00 Rate Base differences and annual changes as follows: 00 Rate Base Difference Annual Data (Wholesale Change less Retail) (Amortization) ) Accumulated Depreciation Fixed values 3,55,000,7,300 ) Taxes Deferred Make Up Adjustment Fixed values 35,0,000,503,000 3) Excess Deferred Taxes Fixed values,50 3,00 ) Taxes Deferred Acct. 8 ACRS/MACRS Fixed values 7,0,000 5,00 s:,5,50 88,000 3 b) Quantification of the Wholesale Rate Base Adjustment The Wholesale Rate Base Adjustment represents the impact on the Wholesale Base TRR relative to the Retail Base TRR of the Wholesale Rate Base Difference for the Prior. Data Value Notes/Instructions Fixed Charge Rate IFPTRR WS L Prior Wholesale Rate Base Difference for Prior 3 Wholesale Rate Base Adjustment 3 * ) Calculation of Wholesale Expense Difference The annual Wholesale Expense Difference impact is the negative of amounts stated in s to 9 above, Column. It represents the effect on expenses (Wholesale less Retail) of amortizing the associated balances each year. If an annual amortization amount affects Income Taxes, the expense difference must be grossed up for income taxes. a) Calculation of the Wholesale South Georgia Income Tax Adjustment to the TRR 5 7 8 9 South Georgia Amortization Composite Tax Rate ("CTR") Tax Gross Up Factor Wholesale South Georgia Income Tax Adjustment to the TRR: 7 BaseTRR WS L 58 (/(CTR)) 5 * 7 Value b) Calculation of "Excess Deferred Taxes" Grossed Up for Income Taxes 0 Annual Amort. of "Excess Deferred Taxes": Tax Gross Up Factor Excess Deferred Taxes Grossed Up for Income Taxes: 8 7 0 * Value
Schedule 5 Wholesale Differences to Base TRR 3 5 7 c) Expense Difference ) Wholesale Depreciation Difference ) Taxes Deferred Make Up Adjustment 3) Excess Deferred Taxes ) Taxes Deferred Acct. 8 ACRS/MACRS Notes/Instructions, Col. 9 9, Col. Expense Difference: 3) Calculation of the Wholesale Difference to the Base TRR 8 9 30 3 3 33 3 Wholesale Rate Base Adjustment Expense Difference Uncollectibles Expense Prior TRR Uncollectibles Expense IFPTRR Subtotal: Franchise Fee Exclusion Wholesale Difference to the Base TRR: 7 Base TRR WS, L 79 IFPTRR WS, L 79 Sum 8 to 3 3 + 33 Value Notes/Instructions: ) Fixed Charge Rate of capital and income tax costs associated with of Rate Base is defined elsewhere in this formula as "AFCRCWIP". ) Input Prior for this Informational Filing in. 3) Calculation: ( 0, ) + (( 0, ) * ( 00)). ) Franchise Fee Exclusion is equal to the Franchise Fee Factor on the FFU WS 5 times 8 + 9. Note
Schedule Tax Rates Calculation of Income Tax Rates ) Federal Income Tax rate Inputs are shaded yellow Federal Income Tax Rate ("FITR") Prior ) Input marginal Federal Income Tax rate for the Prior. See Note. 3 ) Composite State Income Tax Rate 5 Composite State Prior Income Tax 7 Rate ("CSITR") 8 ) See calculation below on 5 based on inputs 9 for apportionment factors and state tax rates. 0 for the applicable Prior Calculation of Composite State Income Tax Rate for the Prior : 3 Apportionment 5 State Factors ("AFs") California ) Input most recent available Apportionment Factors. 7 New Mexico 8 Arizona 9 D.C. 0 Statutory State Tax Rate ("STR") 3 California ) Input STR for the Prior New Mexico for each state. See Note. 5 Arizona D.C. 7 8 Ratio of SCE 9 State Taxable 30 Income to SCE 3 California 3 State Taxable Income 33 California 3) Input most recent available ratios based on 3 New Mexico taxable income from state return filings. 35 Arizona 3 D.C. 37 38 Effective State 39 State Tax Rate 0 California * 3 * 33 New Mexico 7 * * 3 Arizona 8 * 5 * 35 3 D.C. 9 * * 3 Composite State 5 Income Tax Rate = Sum of s 0 to 3 7 3) Capitalized Overhead portion of Electric Payroll Tax Expense 8 Amount 9 Electric Payroll Tax Expense (From BaseTRR WS, 30 50 Capitalized Overhead portion of Electric Payroll Tax Expense Note ) 5 NonCapitalized Overhead portion of Electric Payroll Tax Expense ( 9 50) 5 Notes: ) In the event that statutory marginal tax rates change during the Prior, the effective tax rate used in the formula shall be weighted by the number of days each such rate was in effect. For example, a 35 rate in effect for 0 days superseded by a 0 rate in effect for the remainder of the year will be calculated as: ((.3500 x 0) + (.000 x 5))/35 =.383. ) Enter the capitalized overhead portion of Electric Payroll Tax Expense.
Schedule 7 Allocation Factors Calculation of Allocation Factors Inputs are shaded yellow ) Calculation of Transmission Wages and Salaries Allocation Factor ISO Transmission Wages and Salaries Wages and Salaries 3 Less A&G Wages and Salaries Wages and Salaries wo A&G 5 Results Sharing Less A&G Results Sharing 7 Results Sharing wo A&G Results Sharing 8 nona&g W&S with Results Sharing 9 Transmission Wages and Salary Allocation Factor 0 ) Calculation of Transmission Plant Allocation Factor 3 Transmission Plant ISO 5 Distribution Plant ISO Electric Miscellaneous Intangible Plant 7 Electric Miscellaneous Intangible Plant 8 General Plant 9 General Plant 0 Plant In Service Transmission Plant Allocation Factor Notes Notes FERC Form Reference or Instruction OandM WS 35, Col. 7 FF 35.8b FF 35.7b 3 AandG WS, Note AandG WS, Note 5 + 7 / 8 FERC Form Reference or Instruction PlantStudy WS, PlantStudy WS, 30 PlantInService WS,, C * 9 PlantInService WS,, C 8 * 9 FF 07.0g (L + L5 + L7 + L9) / L0 Prior Value Prior Value
Schedule 8 FF and U Franchise Fees and Uncollectibles Expense Factors ) Approved Franchise Fee Factor(s) From To Inputs are shaded yellow FF Factor Reference U Factor Reference ) Approved Uncollectibles Expense Factor(s) 3 From To 3) FF and U Factors 5 Prior FF Factor U Factor Notes Notes: ) Franchise Fees represent payments that SCE makes to municipal entities for the right to locate facilities within the municipality. Instructions: ) Enter Franchise Fee and Uncollectibles Factors as approved by the California Public Utilities Commission in modules and above. If approved factors changed during Prior, enter both, and note period of time for which each applies in "From" and "To" columns. ) Calculate in module 3 the weighted average FF and U factors from the factors in modules and based on the length of time each FF and U factor was in effect during the Prior at issue.
Schedule 9 Wholesale TRRs CALCULATION OF SCE WHOLESALE HIGH AND LOW VOLTAGE TRRS 3 5 7 TRR Values Inputs are shaded yellow BaseTRR WS, 89 SCE Retail Standby Rate Revenue HVLV WS, 3 HVLV WS, 3 Notes = Wholesale Base TRR = Wholesale TRBAA = HV Wholesale TRBAA = LV Wholesale TRBAA = Standby Transmission Revenues = HV Allocation Factor = LV Allocation Factor Note Note Calculation of High Voltage and Low Voltage components of Wholesale TRR 8 9 0 3 Wholesale Base TRR: CWIP Component of Wholesale Base TRR: NonCWIP Component of Wholesale Base TRR: Components of Wholesale Transmission Revenue Requirement: TOTAL High Voltage Low Voltage See Note 3 See Note See Note 5 s to See Note Sum of s 8,, and Wholesale TRBAA: Less Standby Transmission Revenues: Notes: ) TRBAA is "Transmission Revenue Balancing Account Adjustment". The TRBAA is determined pursuant to SCE's Transmission Owner Tariff and may be revised each, upon commission acceptance of a revised TRBAA amount, or upon the date the Commission orders. ) From Retail Rates worksheet. See : 3) Column is from. Column equals Column *. Column 3 equals Column * 7. ) From CWIP TRR WS, 88. All High Voltage. 5) 8 9 ) Column is from 5. Column equals Column *. Column 3 equals Column * 7.
Schedule 30 Wholesale Rates Calculation of SCE Wholesale Rates (See Note ) SCE's wholesale rates are as follows: ) Low Voltage Access Charge ) Low Voltage Wheeling Access Charge 3) High Voltage UtilitySpecific Rate ) HV Existing Contracts Access Charge 5) LV Existing Contracts Access Charge Calculation of Low Voltage Access Charge: 3 LV TRR = Gross Load = Low Voltage Access Charge = MWh per kwh WholesaleTRRs WS, 3, C3 Gross Load WS / ( * 000) MWh per kwh WholesaleTRRs WS, 3, C3 Gross Load WS / ( 5 * 000) MWh per kwh WholesaleTRRs WS, 3, C Gross Load WS 7 / ( 8 * 000) MW per kw WholesaleTRRs WS, 3, C Gross Load WS 0 / ( * 000) MW per kw WholesaleTRRs WS, 3, C3 Gross Load WS 3 / ( * 000) Calculation of Low Voltage Wheeling Access Charge: 5 LV TRR = Gross Load = Low Voltage Wheeling Access Charge = Calculation of High Voltage Utility Specific Rate: (used by ISO in billing of ISO TAC) 7 8 9 SCE HV TRR = Gross Load = High Voltage UtilitySpecific Rate = Calculation of High Voltage Existing Contracts Access Charge: 0 HV Wholesale TRR = Sum of ly Peak Demands: HV Existing Contracts Access Charge: Calculation of Low Voltage Existing Contracts Access Charge: 3 5 LV Wholesale TRR = Sum of ly Peak Demands: LV Existing Contracts Access Charge: Notes: ) SCE's wholesale rates are subject to revision upon acceptance by the Commission of a revised TRBAA amount. See Note on WholesaleTRRs worksheet.
Schedule 3 High and Low Voltage Gross Plant Derivation of High Voltage and Low Voltage Gross Plant Percentages Determination of HV and LV Gross Plant Percentages for ISO Transmission Plant in accordance with ISO Tariff Appendix F, Schedule 3, Section. A) ISO Plant from Prior Classification of Facility: Input cells are shaded yellow ISO Gross Plant s: HV Transmission s 3 LV Transmission s Transmission s: 5 Substations: 7 HV Substations (>= 00 kv) 8 Straddle Substations (Cross 00 kv boundary LV Substations (Less Than 0kV) 9 0 all Substations s and Substations 3 5 Gross Plant That can directly be determined to be HV or LV: High 7 Voltage 8 Land 9 Structures 0 Determined HV/LV: Gross Plant Percentages (Prior ): 3 Straddling Transformers HV and LV Gross Plant for Prior 5 7 B) Gross Plant Percentage for the Rate Effective Period: 8 9 High 30 Voltage 3 HV and LV Gross Plant for Prior 3 In Service Additions in Rate Effective Period: 33 CWIP in Rate Effective Period 3 HV and LV Gross Plant for REP 35 3 HV and LV Gross Plant Percentages: 37 (HV Allocation Factor and 38 LV Allocation Factor) Land Structures HV Land HV Structures LV Land LV Structures HV/LV Transformers Low Voltage Notes: From above From above Sum of lines 8 and 9 Percent of Straddling Transformers split by Gross Plant Percentages Sum of lines 0 and 3 Low Voltage Notes: 3 Average: PlantAdditionsWS, 7, Cols and 3. 3 Average: CWIP WS, 9, Col. 3 + 3 + 33 Percent of on 3
Schedule 3 Gross Load Calculation of Forecast Gross Load SCE Retail Sales at ISO Grid level: Pump Load forecast: 3 Forecast Gross Load: Forecast CP Load: MWh Calculation 0 + Notes: ) Latest SCE approved sales forecast as of 5 of each year. ) SCE pump load forecast as of 5 of each year. Note Note Sum of above Note
Schedule 33 Retail Transmission Rates Calculation of SCE Retail Transmission Rates Retail Base TRR: ) Derivation of " Demand Rate" and " Energy Rate": Note 3c 3c CPUC Rate Group Domestic GS TC GS TOUGS3 TOU8SEC TOU8PRI TOU8SUB includes 0 kv PA PA TOUAG TOUPA5 Street Lighting TOU8SEC (Standby) TOU8PRI (Standby) TOU8SUB (Standby) includes 0 kv Ag TOU <= 00 kw Ag TOU > 00 kw s: Applies to kwh charges Allocated costs CP factors Input cells are shaded yellow Note = Retail Base TRR * : a b c d e f g h i j k l m n o p q r s 3 5 7 8 9 0 3a 3b 3c BaseTRR WS, 8 Col Note 3 Maximum demand (excess CRC) MW ) Determination of Standby Demand Rates for Rate Groups with DirectlyAllocated Costs from : from 30:Col from 30: Note 8 CPUC Rate Group TOU8SEC TOU8PRI TOU8SUB includes 0 kv TOU8SUB below 0 kv TOU8SUB 0 kv 3d TOU8SUB (Standby) includes 0 kv TOU8SUB (Standby) below 0 kv 3d 3d TOU8SUB (Standby) 0 kv Allocated Costs CP Backup CP Col Note 5 Col 7 Note Col 8 Note 8 Applies to monthly Applies to monthly maximum kw contracted standby demand charges kw demand charges Forecast Billing Determinants: Sales (GWh) Note Col Note 9 Note 0 Allocation to Maximum kw demand (Excess 0 Applies to monthly Applies to monthly maximum kw contracted standby demand charges kw demand charges Forecast Billing Determinants Standby demand (CRC) MW Col 9 Note 8 energy rates /kwh demand rates /kwmonth Col from : (, Col 9) Allocation to contract Standby kw demand Standby demand (CRC) MW Col 7 Note 0 kv Maximum demand (excess CRC) MW Col 8 Standby demand (CRC) rates /kw Notes Note 8 Note 7 Note 7 Note 7 0 kv Standby demand (CRC) MW Notes Note 7 Note 7 Note 7 Note 7 Note 7
Schedule 33 Retail Transmission Rates 5 7 3) EndUser Transmission Rates from : 8 9 0 3 a b c d e f g h h CPUC Rate Group Domestic GS TC GS TOUGS3 TOU8SEC TOU8PRI TOU8SUB TOU8SUB below 0 kv TOU8SUB 0 kv PA PA TOUAG TOUPA5 Street Lighting TOU8SEC (Standby) TOU8PRI (Standby) TOU8SUB (Standby) TOU8SUB (Standby) below 0 kv p p TOU8SUB (Standby) 0 kv q Ag TOU <= 00 kw r Ag TOU > 00 kw s 5 s: h i j k l m n o p Note Note 3 Col Col Note Note 5 Energy Charge /kwh Maximum demand Charge /kwmonth (excess Standby) Col 7 Note Retail Transmission Rates Col 8 Col 9 Note 7 Note 7 Standby demand Charge /kwmonth Maximum demand Charge /HPmonth (excess Standby) 0 Maximum demand revenue (excess CRC) Note 8 Note 7 Note 7 Note 7 Note 7 Allocated Costs Standby demand (CRC) Notes: ) See s 8a, 8b, etc. ) Sales Forecast in total Gigawatt hours usage applies to nondemand schedules, and it's the customers' total annual kwh consumption. 3) Sales Forecast pertaining to the sum of monthly maximum Megawatt demand applies to demand schedules (the customer's monthly metered maximum kw demand). ) Sales Forecast pertaining to the sum of monthly contracted standby Megawatt demand applies to standby schedules (the customer's monthly contracted standby kw demand). 5) For nondemand Schedules, " Energy Rate /kwh" = : / ( :) *,000,000. ) For demand Schedules, " Demand Rate /kw" = : / ( :(Col + )) *,000. However, the demand Rate for "TOU8Sub" which includes "0 kv" are calculated together (i.e., using sum of "Maximum Demand" and "Standby Demand" of each). 7) These Rate Groups are being proposed in SCE's 0 General Rate Case at the California Public Utilities Commission, but may not be in effect until 03. 8) TOU8SUB (below 0 kv) is derived by multiplying the total allocated costs of TOU8Sub (includes 0 kv) of, by the ratio of the CP ( 3:) pertains to TOU8SUB (below 0 kv) to TOU8SUB (includes 0 kv). TOU8SUB (0 kv) is derived by subtracting the TOU8SUB (below 0 kv) from The total allocated costs TOU8SUB (includes 0 kv). 9) 3:( ). 0) 3: * 3:( / ). ) 3:( / Col ) *,000. ) :( ). However, for TOU8SEC, TOU8Pri, TOU8SUB (includes 0 kv), TOU8SUB (below 0 kv), TOU8SUB (0 kv) See corresponding 3:Col. 3) : * :Col 7 *,000. However, for TOU8SEC, TOU8Pri, TOU8SUB (includes 0 kv), TOU8SUB (below 0 kv), TOU8SUB (0 kv) See corresponding 3:. ) From :Col (applicable to all kwh usage). 5) : / :Col *,000 (applicable to monthly maximum kw demand). However, for TOU8SUB (below 0 kv), it is derived by the corresponding : / :(Col Col 8) *,000. And TOU8SUB (0 kv) is equal to the corresponding : / :Col 8 *,000. ) Minimum of (TOU8SEC from 3:Col 7, or corresponding :Col 7). However, for TOU8SEC, TOU8Pri, TOU8SUB (below 0 kv), TOU8SUB (0 kv) equals to the Standby Demand Rate from corresponding 3:Col 7. 7) Applicable to Connected Load options in /HP (Horsepower). Connected load rate is equal to the /kw in corresponding :(Col,Col 7) time 75. 8) 0 kv service is part of the TOU8SUB rate group, however, intervening parties in the CPUC proceedings agreed to identify these customers for rate design treatment purposes Standby demand Charge /HPmonth Notes Note 7 Note 7 Note 7
Schedule 33 Retail Transmission Rates Rate Schedules in each CPUC Rate Group: CPUC Rate Group 7a Domestic 7b Domestic Con't. 7c GS 7d TC 7e GS 7f TOUGS3 7g TOU8SEC 7h TOU8PRI 7i TOU8SUB 7i TOU8SUB below 0 kv 7i TOU8SUB 0 kv 7j PA 7k PA 7l TOUAG 7m TOUPA5 7n Street Lighting 7o TOU8SEC (Standby) 7p TOU8PRI (Standby) 7q TOU8SUB (Standby) 7q TOU8SUB (Standby) below 0 kv 7q 7r 7s 7t 7u 7v Rate Schedules included in Each Rate Group in the Rate Effective Period All rate options, including D, DAPS, DAPSE, DCARE, DE, DM, DMS, DMS, DMS3, DS, TOUD, TOUD, and TOUEV, TOUDT and TOUDTEV All rate options, including GS, GSAPS, GSAPSE, TOUEV3, and TOUGS. All rate options, including TC, WTR, and WiFi. All rate options, including GS, GSAPS, GSAPSE, and TOUEV. All rate options, including TOUGS3 and TOUGS3SOP All rate options, including TOU8, TOU8BU and RTP based on voltage of service All rate options, including TOU8, TOU8BU and RTP based on voltage of service All rate options, including TOU8, TOU8BU and RTP based on voltage of service All rate options, including TOU8, TOU8BU and RTP based on voltage of service All rate options, including TOU8, TOU8BU and RTP based on voltage of service All rate options, including PA. All rate options, including PA. All rate options, including TOUPA, PARTP, and TOUPASOP All rate options, including TOUPA5. All rate options, including AL, DWL, LS, LS, LS3, and OL. TOU8SUB (Standby) 0 kv Ag TOU <= 00 kw Ag TOU > 00 kw Recorded CP Load Data by Rate Group (MW) Col =( + + Col 3) / 3 Three Average Col =(Col * ) Col 7 from : Col 8 = Col */Col * Col 7 Col 9 = Col 8 / Sum of Col 8 0 Recorded Average Sales GWh Sales Forecast GWh Loss Adjusted Average CP CP factors Notes CP MW 8a 8b 8c 8d 8e 8f 8g 8h 8i 8j 8k 8l 8m 8n 8o 8p 8q 8r 8s 8t 8u 9 CPUC Rate Group Domestic GS TC GS TOUGS3 TOU8SEC TOU8PRI TOU8SUB includes 0 kv PA PA TOUAG TOUPA5 Street Lighting TOU8SEC (Standby) TOU8PRI (Standby) TOU8SUB (Standby) includes 0 kv Ag TOU <= 00 kw Ag TOU > 00 kw s: 0 0 losses 0 0 0 0 0 Note 7 Note 7 Note 7 Note 7 Note 7 0.00
Schedule 33 Retail Transmission Rates Allocation Factors for Backup Rates: Backup demand (0709 average) losses CP Backup CP Notes CP MW CPUC Rate Group 30a TOU8SEC 30b TOU8PRI 30c TOU8SUB includes 0 kv 30c TOU8SUB below 0 kv CP (0709 average) TOU8SUB 0 kv 30c 30d TOU8SEC (Standby) 30e TOU8PRI (Standby) 30f TOU8SUB (Standby) includes 0 kv TOU8SUB (Standby) below 0 kv 30f 30f Col = ( * ) = ( * ) Loss Adjusted Col Note 8 Note 7 Note 7 Note 7 Note 7 Note 7 CP Allocation Percentage Allocated Retail Base TRR () Forecast Sales (GWh) from : from : Forecast Standby Demand (MW) from :(Col 5,Col 9) Base TRR Energy Charge (/kwh) Col from : Forecast Maximum Demand (MW) Col from :(Col,Col 8) TOU8SUB (Standby) 0 kv EndUser Transmission Rates Retail Rate Group 3a Domestic 3b 3c 3d 3e GS TC GS TOUGS3 3f TOU8SEC 3g TOU8PRI 3h TOU8SUB below 0 kv 3i TOU8SUB 0 kv 3j 3k 3l 3m PA PA TOUAG TOUPA5 3n Street Lighting 3o System from : Base TRR Demand Charge (/kw) Col 7 Standby Demand Charge (/kw) Col 8 from :Col from :Col 7
Schedule 33 Retail Transmission Rates EndUser Transmission Rates Revenues Retail Rate Group Forecasted kwh Charge Revenue () 3:( * Col ) * 0^ Forecasted ly Maximum Demand Revenue () 3:(Col * Col 7) *,000 Forecasted ly Standby demand Revenue (M) 3:( * Col 8) *,000 Forecasted Retail Base Transmission Revenue () Col 3:( + Col + ) 3a Domestic 3b 3c 3d 3e GS TC GS TOUGS3 3f TOU8SEC 3g TOU8PRI 3h TOU8SUB below 0 kv 3i TOU8SUB 0 kv 3j 3k 3l 3m PA PA TOUAG TOUPA5 3n Street Lighting 3o System