ࡱ>  DF?@ABC{!` xbjbj\\ >>DnnnD~~~trhL ީ"yLG#%%%%%%$ThpI9nW"yIA.B Rn##kL"nO fX~3&#7<;,Y,0OO8,n=II_^N6Wğ6W Cost Effectiveness Evaluation Calculator Tool v.3b Quick Guide and Equation Reference (v.3b2) This document provides a brief guide to the user inputs and outputs. This is followed by a detailed presentation of the equations used by the Calculator Tool. The last section presents a discussion of the data management issues and steps taken in developing the inputs for the tool. Table of Contents  TOC \o "1-3" \h \z \u  HYPERLINK \l "_Toc142186241" Cost Effectiveness Evaluation Calculator Tool  PAGEREF _Toc142186241 \h 1  HYPERLINK \l "_Toc142186242" Quick Guide and Equation Reference for Version 3  PAGEREF _Toc142186242 \h 1  HYPERLINK \l "_Toc142186243" Inputs Summary  PAGEREF _Toc142186243 \h 2  HYPERLINK \l "_Toc142186244" Output  PAGEREF _Toc142186244 \h 7  HYPERLINK \l "_Toc142186245" Notes on the Tests and Outputs  PAGEREF _Toc142186245 \h 7  HYPERLINK \l "_Toc142186246" Outputs  PAGEREF _Toc142186246 \h 7  HYPERLINK \l "_Toc142186247" Output by Measure  PAGEREF _Toc142186247 \h 14  HYPERLINK \l "_Toc142186248" Batch Processing  PAGEREF _Toc142186248 \h 16  HYPERLINK \l "_Toc142186249" Processing Choice  PAGEREF _Toc142186249 \h 16  HYPERLINK \l "_Toc142186250" Input File Rows  PAGEREF _Toc142186250 \h 17  HYPERLINK \l "_Toc142186251" Control Tab  PAGEREF _Toc142186251 \h 18  HYPERLINK \l "_Toc142186252" Equations  PAGEREF _Toc142186252 \h 19  HYPERLINK \l "_Toc142186253" Net July-Sept Peak (CP_kW_N_TOT[Smr])  PAGEREF _Toc142186253 \h 19  HYPERLINK \l "_Toc142186254" Net Dec-Feb Peak (CP_kW_N_TOT[Wtr])  PAGEREF _Toc142186254 \h 20  HYPERLINK \l "_Toc142186255" Noncoincident Peak (Net NCP)  PAGEREF _Toc142186255 \h 21  HYPERLINK \l "_Toc142186256" Noncoincident Peak by Year (NNCP[t])  PAGEREF _Toc142186256 \h 21  HYPERLINK \l "_Toc142186257" CEC Peak (Net CEC)  PAGEREF _Toc142186257 \h 22  HYPERLINK \l "_Toc142186258" Annual Net kWh (Annual_kWh)  PAGEREF _Toc142186258 \h 22  HYPERLINK \l "_Toc142186259" Lifecycle Net kWh (Lifecycle_kWh)  PAGEREF _Toc142186259 \h 22  HYPERLINK \l "_Toc142186260" Annual Net Therms (Annual_Therms)  PAGEREF _Toc142186260 \h 22  HYPERLINK \l "_Toc142186261" Lifecycle Net Therms (Lifecycle_Therms)  PAGEREF _Toc142186261 \h 23  HYPERLINK \l "_Toc142186262" Cost Effectiveness (Lifecycle Present Value Dollars)  PAGEREF _Toc142186262 \h 23  HYPERLINK \l "_Toc142186263" Cost  PAGEREF _Toc142186263 \h 23  HYPERLINK \l "_Toc142186264" TRC Cost (TOTCOSTTRC)  PAGEREF _Toc142186264 \h 23  HYPERLINK \l "_Toc142186265" PAC Cost (TotCostPAC)  PAGEREF _Toc142186265 \h 24  HYPERLINK \l "_Toc142186266" RIM Cost (TotCostRIM)  PAGEREF _Toc142186266 \h 24  HYPERLINK \l "_Toc142186267" Lifecycle Benefit  PAGEREF _Toc142186267 \h 25  HYPERLINK \l "_Toc142186268" Electric TRC Benefits (NetPVBenTOT[E])  PAGEREF _Toc142186268 \h 25  HYPERLINK \l "_Toc142186269" Gas TRC Benefits (NetPVBenTOT[G])  PAGEREF _Toc142186269 \h 27  HYPERLINK \l "_Toc142186270" Levelized Cost and Benefit  PAGEREF _Toc142186270 \h 28  HYPERLINK \l "_Toc142186271" Discounted Electric Reductions (kWhD[N])  PAGEREF _Toc142186271 \h 28  HYPERLINK \l "_Toc142186272" Discounted Gas Reductions (ThD[N])  PAGEREF _Toc142186272 \h 29  HYPERLINK \l "_Toc142186273" Levelized Cost  PAGEREF _Toc142186273 \h 29  HYPERLINK \l "_Toc142186274" Levelized Benefits  PAGEREF _Toc142186274 \h 30  HYPERLINK \l "_Toc142186275" Levelized Benefit Cost  PAGEREF _Toc142186275 \h 30  HYPERLINK \l "_Toc142186276" Emissions Reductions  PAGEREF _Toc142186276 \h 32  HYPERLINK \l "_Toc142186277" Electric Reductions: CO2 tons per year (Emission[E][CO2])  PAGEREF _Toc142186277 \h 32  HYPERLINK \l "_Toc142186278" Gas Reductions: CO2 tons per year (Emission[G][CO2])  PAGEREF _Toc142186278 \h 32  HYPERLINK \l "_Toc142186279" Monthly Impacts (IMP_MO[X], IMP_MO[Th])  PAGEREF _Toc142186279 \h 33  HYPERLINK \l "_Toc142186280" Sector and End Use Shape Combinations  PAGEREF _Toc142186280 \h 34 Cost Effectiveness Evaluation Calculator Tool 1 Quick Guide and Equation Reference 1 Inputs Summary 2 Output 5 Notes on the Tests and Outputs 5 Outputs 6 Output by Measure 12 Equations 13 Net July-Sept Peak (CP_kW_N_TOT[Smr]) 13 Net Dec-Feb Peak (CP_kW_N_TOT[Wtr]) 14 Noncoincident Peak (Net NCP) 15 Noncoincident Peak by Year (NNCP[t]) 16 CEC Peak (Net CEC) 16 Annual Net kWh (Annual_kWh) 16 Lifecycle Net kWh (Lifecycle_kWh) 17 Annual Net Therms (Annual_Therms) 17 Lifecycle Net Therms (Lifecycle_Therms) 17 Cost Effectiveness (Lifecycle Present Value Dollars) 18 Cost 18 TRC Cost (TOTCOSTTRC) 18 PAC Cost (TotCostPAC) 19 RIM Cost (TotCostRIM) 19 Lifecycle Benefit 19 Electric TRC Benefits (NetPVBenTOT[E]) 19 Gas TRC Benefits (NetPVBenTOT[G]) 21 Levelized Cost and Benefit 22 Discounted Electric Reductions (kWhD[N]) 22 Discounted Gas Reductions (ThD[N]) 23 Levelized Cost 23 Levelized Benefits 24 Levelized Benefit Cost 24 Emissions Reductions 26 Electric Reductions: CO2 tons per year (Emission[E][CO2]) 26 Gas Reductions: CO2 tons per year (Emission[G][CO2]) 27 Monthly Impacts (IMP_MO[X], IMP_MO[Th]) 27 Sector and End Use Shape Combinations 29  Inputs Summary ItemLocationCommentProposer NameCell D4Text fieldProgram NameCell D5Text fieldFirst Year of Program ImplementationCell D7Integer (2006-2008). For program year 2006, leave as 2006.Contact InformationD9:D13Text fieldsMarket SectorsE14:E15Text fields. Only used for PG&E reporting. Do not affect calculations.Program BudgetAdministrative Costs: Overhead and G&AG3Total cost over the program implementation cycle. Entered in nominal dollarsAdministrative Costs: Other Admin CostsG4Total cost over the program implementation cycle. Entered in nominal dollarsMarket/OutreachG5Total cost over the program implementation cycle. Entered in nominal dollarsDirect Implementation: Activity Installation Hardware & materials Rebate processing and inspectionG7 to G10Total cost over the program implementation cycle. Entered in nominal dollars. These cell entries are for non-incentive related costs. Incentive and rebate information is entered on a per-measure basis or in cell I4.Total Incentives and RebatesG11Not a user entry. Sum of values in Cells I4 to I8EM&VG12Entered in nominal dollars.Costs recovered from other sources.I12Entered in nominal dollars. User Input IncentiveI4Entered in nominal dollars. Use this cell for incentives and rebates that are not calculated on a per unit installed basis. Users should be careful to avoid double counting incentives. If this cell is used, only enter incentive values in columns K through M for measures that are not included in this incentive calculation.Direct Install RebateI5 to J5Not a user entry. Nominal and present value totals based on rebates per unit entered in column K. Note that the value shown in column I is in nominal dollars, and column J is a present value (to reflect the expected timing of the payments). Nominal values are used for program budget reporting and PV is used for the cost effectiveness and levelized cost calculations. Direct Install LaborI6 to J6Not a user entry. Nominal and present value totals based on rebates per unit entered in column K. See above for further discussion of nominal and PV dollars.Direct Install MaterialsI7 to J7Not a user entry. Nominal and present value totals based on rebates per unit entered in column K. See above for further discussion of nominal and PV dollars.Program Inputs (Inputs begin in Row 17)Program NameCol ANot a user entry. Hidden text field used in reporting information to the Energy Division.Measure NameCol BText fieldDEER RunIDCol CNumeric filed corresponding to DEER database.Climate zoneCol DSelect from drop-down list. Cannot be left blank. Used to determine the impacts and costs for the measure. System applies the generation and T&D avoided costs from the climate zone with the lowest average generation and transmission avoided capacity cost over 25 years. Note that Climate zone 3 has been subdivided into two subzones. Climate zone 3A is for San Francisco and the Peninsula. Climate Zone 3B is for the East Bay. See the attachment for a complete listing of Cities and Climate Zones.Target SectorCol ESelect from the Drop Down list. This entry is used to determine whether to use a residential or non-residential TOU correction factor where applicable. For the PG&E, SCE and SoCalGas tools, this entry is also used to limit the measure end use shapes listed in the drop down entries in Column F. This entry is not used for calculation purposes into constrain measure end use shapes in the SDG&E model, although it is used for reporting purposes.Measure End Use ShapeCol FSelect from the drop-down list. Note that the list of measures can vary depending upon the Target Sector selected in Column E. For PG&E, SCE, and SoCal Gas, this entry will determine if a measure could receive a TOU correction factor adjustment. Having one of the following end use shapes is a necessary, but not sufficient, condition to qualify for the TOU correction adder. In order to receive a TOU correction factor adjustment, a measure must also have a positive entry in column Z % Eligible for TOU AC Adjustment. PG&E: 26 = Res. Central Air Conditioning 22 = Res. Ht. Pump Cooling 29 = Res. New Const. Cooling 33 = Res. Insul. Cen. A/C 35 = Res. Ceil. Insul. HP Cooling 37 = Res. Wall Insul. HP Cooling 39 = Res. Flr. Insul. HP Cooling 45 = Res. Dir. Assist. Evap. Cooler 3 = Commercial HVAC SCE: AC-NC New_AC-Ret; AC_Cooling-RC HeatPump_ThroughWall-RC Package_AC-NC <65K_AC_Split-NC <65K_AC_Pckg-NC 65K-135K_Air_AC-NC 65K-135_Wtr_AC-NC >135K_Air_AC-NC >135K_Wtr_AC-NC <65K_EvapCool-NC Evap_Cooling-Ret New_HtPmp-Ret Replace_Chiller-Ret Wtr_Cool_Chiller-NC SoCal Gas: AC_Cooling AC >135K_Air_AC >135K_Wtr_AC New_AC New_HtPmp Reduce_Cooling_Load CZ, Sector, Measure combination found?Col GNot a user input. If FALSE, then recheck the measure end use shape drop down list to verify that you have selected a valid measure. Typically, the FALSE warning will appear when the user selects a measure based on a certain Sector, but then changes the Sector without updating the measure choice. Note: This column is not used in PG&Es residential tool or in SDG&Es tool.Measure TypeCol HSelect from drop-down list. This entry is used to determine the Measure Life, based on values in the Program Manual. Users may also specify a life using the Generic Life entries at the bottom of the drop down list.Program TypeCol ISelect from drop-down list. This entry is used to determine the Net-to-Gross ratio, based on values in the Program ManualUnit DefinitionCol JNot used by the spreadsheet. For informational purposes only.Financial Incentive: RebateCol K Per unit rebates paid to the participant by the sponsoring agency. Financial Incentive: Direct Install LaborCol L Per unit labor provided to the participant by the sponsoring agencyproposed Program. Financial Incentive: Direct Install MaterialsCol MPer unit materials provided to the participant by the sponsoring agencyproposed Program. Gross Incremental Measure CostCol N Cost of the efficient equipment less the cost of the standard efficiency equipment. Same Use value as in DEER as applicable. Include initial capital costs, including sales tax, ongoing O&M costs including fuel, removal costs less salvage value, and value of customers time in arranging for installation (if significant). Subtract participant avoided costs for alternate fuel devices.For direct install programs, enter the sum of Direct Install Labor and Direct Intall Materials (Col L + Col M) Note that if the sum of the three Financial Incentives columns exceeds the Gross Incremental Measure Cost, those entries will be flagged with red cell shading. This is for informational purposes only. Calculations are not affectedGross Unit Annual Electricity SavingsCol OAnnual net kWh reduction attributable to the installation of one unit of the measure.Electric Rate ScheduleCol PSelect from drop-down list. Used to determine revenue loss for RIM test.Demand Scale FactorCol QNot a user input. Indicates kWh if capacity savings are calculated using annual kWh reductions, or kW if capacity savings are calculated using summer peak kW reductions.Summer Peak kW Savings per unitCol RSummer peak period kW reduction attributable to installation one unit of the measure. Only required for cost effectiveness calculations if Col Q indicates kW. Otherwise, the cell is grayed out, indicating no input is needed (except for SDG&E). SDG&E reports DEER kW which uses the values entered in Col R, regardless of whether the cell is grayed out. For SDG&E, enter kW impact estimates from DEER even if the cell is grayed out.)Gross Unit Annual Gas SavingsCol SAnnual net therms reduction attributable to the installation of one unit of the measure.Gas SectorCol TSelect from the drop-down list. Used to determine the gas avoided costs to apply to the measure. Note: This column is not a user input in PG&Es residential tool.Gas Rate ScheduleCol USelect from drop-down list. Used to determine revenue loss for RIM test. Note: This column is not a user input in PG&Es residential tool.Gas Savings ProfileCol VSelect from the drop-down list. Used to determine the gas avoided costs to apply to the measure. Summer Only: All gas savings occur in April through September. Winter Only: All gas savings occur in October through March Annual: Gas savings occur uniformly throughout the year.Combustion TypeCol WDetermines the rate of emission savings per MMBTU of reduced natural gas usage from gas conservation. (lbs of CO2, NOX, and PM-10). Not a user input for PG&E. Not used for SCE. Select from a drop down list for SDG&E and SoCalGas. Res Furnace is used as a default if there is no user selection. Effective Useful LifeCol XDetermined by the spreadsheet, based on Measure Type.Net to-Gross RatioCol YDetermined by the spreadsheet, based on Program Type.% Eligible for TOU AC AdjustmentCol ZUser input between 0 and 100%, with 100% for those cases where the entire measure receives the AC TOU correction factor. Note that the measure will not receive a correction factor adjustment for PG&E, SCE, or SoCalGas if the measure end use shape does not qualify (see discussion for Col F above).Installation ScheduleInstallations by YearCol AA to Col AGUsed by SCE, SDG&E and SoCalGas. For SCE, all annual installations are assumed to occur at the beginning of the first quarter of the year. For SDG&E and SoCalGas, the The annual installations are assumed to occur uniformly over the 4 quarters in each year.Installations by QuarterCol AI to Col BIBJ.User input for PG&E only. All others are allocated units based on the annual installations in the prior columns. Number of incremental units installed by the beginning end of the quarter. For simplicity, and end of quarter (rather than mid-quarter) convention is used. For example, Q1 2006 would have all units installed prior toat midnight on 1/13/31/2006. Q2 2006 would have all units installed from 1/1/2006 throughon 3/316/30/2006. Q3 2006 would have all units installed from 4/1/2005 through 6/30/2006. This convention of units installed at the beginning end of the quarter results in slightly conservative estimates of benefits, as programs could be installed up to three months prior to recognition of their savings. Compared to a middle of the quarter convention, this approach results in present values that are 1.5% lower. As the same convention applies to both costs and benefits, the impact on net benefits or benefit cost ratios is likely negligible.Total Number of UnitsCol BKNot a user entry.CommentsCol AJBLFor informational purposes only. Not used in the calculations. Output Notes on the Tests and Outputs Total Resource Cost Test (With externalities) ItemCommentTax Credits (TC)No explicit input for tax credits. Levelized benefits per kWh Uses Net discounted kWh to correspond to Net benefits (NTG ratio adjusted) CEC kWCEC kW reported in the tools for the June filings were based on a snapshot of units in place and still operational as of a certain date (dates are specified in the Output detail section). This can result in a lower estimate of CEC kW than if all units were counted (including those with useful lives that expire before the snapshot date). After the June materials were prepared, PG&E requested that the change be made to their tools to include all units, regardless of useful lives. That change has been made for PG&Es tools only. PG&Es June filing does NOT reflect the change. Outputs ItemLocationCommentTotal Program BudgetD4Total of all program budget items, including rebates and incentivesIncentives and Rebates ($nominal)D5Nominal total incentives and rebates. These are already included in the Total Program Budget in D4. They are shown separately so that they can be removed from the TRC test.Incentives and Rebates ($PV)E5Present value of total incentives and rebates.Net Incremental Measure CostD6Present value of participant costs before any incentives or rebates, multiplied by Net to Gross RatioProgram ImpactsAnnual Net kWhC10:C11Sum across all measures of their annual kWh savings adjusted for their net-to-gross ratio. Based on total units installed, regardless of useful life. (See Annual_kWh) If a program has units that have short useful lives such that they fail prior to the end of the implementation period, the maximum annual kWh savings actually attained in any year will be lower than what is shown here. In addition, this metric does not reduce annual kWh for measures that are installed after the 1st quarter in a year. Lifecycle Net kWhD10:D11Sum across all measures of their lifecycle kWh savings, adjusted for their net-to-gross ratios. Lifecycle savings = Annual kWh * Measure Life (in yrs) * Net-to-gross ratio.* Total units installed. (See Lifecycle_kWh). Note: This metric is NOT based on the units in place during the third quarter of year 4.Annual Net ThermsE10-E11Sum across all measures of their annual therm savings adjusted for their net-to-gross ratio. (See Annual_Therms) For SCE, this metric is based on units installed and still effective in the quarters identified for Net July-Sept Peak. For SoCalGas and PG&E, this metric is based on total units installed, regardless of useful life. Lifecycle Net ThermsF10:F11Sum across all measures of their lifecycle therm savings, adjusted for their net-to-gross ratios. Lifecycle savings = Annual therms * Measure Life (in yrs) * Net-to-gross ratio.* Total units installed. (See Lifecycle_Therms). Note: This metric is NOT based on the units in place during the third quarter of year 4.therms.Net July-Sept Peak (kW)C9G10:G11Sum across all measures of their average July through September coincident peaks. Peak is measured based on cumulative units installed but not past the end of their useful lives in the following quarters: PG&E: 3rd Qtr 2011 SDG&E: 3rd Qtr 2009 SCE: 4th Qtr 2008 SoCalGas: 3rd Qtr 2009 Coincident peak is defined as the load during the five highest system load hours in each month. (See Equation CP_KW_N_TOT[Smr]). Value is adjusted for the net to gross ratio. Net Dec-Feb Pk (kW)D9H10:H11Sum across all measures of their average December, January, and February coincident peaks. Peak is based on units installed and still effective in the quarters identified for Net July-Sept Peak Coincident peak is defined as the load during the five highest system load hours in each month. (See Equation CP_KW_N_TOT[Wtr]). Value is adjusted for the net to gross ratio.Net Measure NCP (kW)E9Sum across all measures of their individual maximum demands in the year, adjusted for net-to-gross ratios. Peak is based on units installed and still effective in the quarters identified for Net July-Sept Peak. (See Net NCP)Net CEC (kW)F9I10:I11Sum across all measures of their CEC peak demand. For SCE, SoCalGas and SDG&E, the peak is based on units installed and still effective in the quarters identified for Net July-Sept Peak. (See Net CEC). For PG&E, their June filing uses this same approach. PG&Es filed tool, however, changes the calculation to use all units installed, regardless of useful life.User Entered kWJ10:J11Sum across all measures installed in the corresponding years, multiplied by their DEER peak grid kW savings adjusted for their net-to-gross ratio. For those cases where peak grid savings are not available, parties should estimate peak reductions consistent with the DEER definition for weather sensitive loads. Annual Net kWhG9Sum across all measures of their annual kWh savings adjusted for their net-to-gross ratio. Based on total units installed, regardless of useful life. (See Annual_kWh) If a program has units that have short useful lives such that they fail prior to the end of the implementation period, the maximum annual kWh savings actually attained in any year will be lower than what is shown here. In addition, this metric does not reduce annual kWh for measures that are installed after the 1st quarter in a year. Lifecycle Net kWhH9Sum across all measures of their lifecycle kWh savings, adjusted for their net-to-gross ratios. Lifecycle savings = Annual kWh * Measure Life (in yrs) * Net-to-gross ratio.* Total units installed. (See Lifecycle_kWh). Note: This metric is NOT based on the units in place during the third quarter of year 4.Annual Net ThermsI9Sum across all measures of their annual therm savings adjusted for their net-to-gross ratio. (See Annual_Therms) For SCE, this metric is based on units installed and still effective in the quarters identified for Net July-Sept Peak. For SoCalGas and PG&E, this metric is based on total units installed, regardless of useful life. Lifecycle Net ThermsJ9Sum across all measures of their lifecycle therm savings, adjusted for their net-to-gross ratios. Lifecycle savings = Annual therms * Measure Life (in yrs) * Net-to-gross ratio.* Total units installed. (See Lifecycle_Therms). Note: This metric is NOT based on the units in place during the third quarter of year 4.therms.Cost Effectiveness Lifecycle Present Value DollarsProgram TRCTRC CostC15C16Total Program Budget + Net incremental measure cost Nominal rebates and incentives (See TOTCostTRC)TRC Benefits: ElectricD15D16Sum of net electric present value benefits for all measures installed over the three years. Net indicates the gross benefits are multiplied by the Net-to-Gross ratios. (See NetPVBenTOT[E])TRC Benefits: GasE15E16Sum of net gas present value benefits for all measures installed over the full implementation period. Net indicates the gross benefits are multiplied by the Net-to-Gross ratios. (See NetPVBenTOT[G])Benefit Cost NPVG15G16TRC Benefits Electric +TRC Benefits Gas TRC CostB/C RatioH15H16(TRC Benefits Electric + TRC Benefits Gas) / TRC Cost. Note that the B/C Ratio is an approximation because any supply costs associated with increased are treated as negative benefits rather than as a cost as in the Standard Practice ManualPAC (Program Administrator Cost Test)PAC CostC16C17Total program budget, including customer incentive payments. (See TOTCostPAC)PAC Benefits:ElectricD16D17Same as TRC testPAC Benefits: GasE16E17Same as TRC testIncentivesF16F17NA. Already included in PAC Cost above PAC Benefit - Cost NPVG16G17PAC Benefits Electric +PAC Benefits Gas + Incentives PAC Cost PAC B/C RatioH16H17(PAC Benefits Electric + PAC Benefits Gas + Incentives) / PAC Cost. Note that the B/C Ratio is an approximation because any costs associated with increased usage are treated as negative benefits rather than as a cost as in the Standard Practice ManualRIM (Ratepayer Impact Measure Test)RIM CostC17C18Total bill reductions plus PAC Cost (See TOTCostRIM)RIM Benefits:ElectricD17D18Same as TRC testRIM Benefits: GasE17E18Same as TRC testRIM Benefit - Cost NPVG17G18RIM Benefits Electric + RIM Benefits Gas + Incentives RIM Cost RIM B/C RatioH17H18(RIM Benefits Electric + RIM Benefits Gas + Incentives) / RIM Cost. Note that the B/C Ratio is an approximation because any costs associated with increased usage are treated as negative benefits rather than as a cost as in the Standard Practice ManualLevelized Cost and Benefit (discounted present values)Discounted kWh (all tests)C24C25:C26C27Discounted lifecycle avoided kWh, adjusted for Net-to-gross ratio for each measure. (See kWhD[N])Discounted Therms (all tests)D28D29:D30D31Discounted lifecycle avoided therms, adjusted for Net-to-gross ratio for each measure. (See ThD[N])TRC Levelized CostE24E25, E28E29(TRC Benefits) less the (TRC Benefits Costs) (See LC[TRC][E], LC[TRC][G])PAC Levelized CostE25E26, E29E30(PAC Benefits) less the (PAC Benefits Costs) (See LC[PAC][E], LC[PAC[G])RIM Levelized Cost: ElectricE26E27RIM Cost * [RIM Electric Benefit /(RIM Electric Benefit + RIM Gas Benefit)] / Discounted kWh (See LC[RIM][E])RIM Levelized Cost: GasE30E31RIM Cost * [RIM Gas Benefit /(RIM Electric Benefit + RIM Gas Benefit)] / Discounted kWh (See LC[RIM][G])TRC Levelized BenefitsF24F25, F28F29TRC benefits (by fuel type) divided by the TRC discounted kWh or Therms. (See LB[TRC][E], LB[TRC][G])PAC Levelized BenefitsF25F26, F2930PAC benefits (by fuel type) divided by the PAC discounted kWh or Therms. (See LB[TRC][E], LB[TRC][G])RIM Levelized BenefitsF26F27, F30F31RIM benefits (by fuel type) divided by the RIM discounted kWh or Therms. (See LB[TRC][E], LB[TRC][G])TRC Levelized Benefit - CostF24F25, F28F29Sum over all measures of TRC benefits less the allocated TRC costs for each measure. For each measure, unit costs (net IMC) are allocated between electric and gas in proportion to the benefits by fuel for that measure. The remaining program costs are allocated to each measure based on each measures share of the total electric and gas benefits. Once allocated to each measure, the remaining program costs are allocated to electric and gas in proportion to the benefits by fuel for that measure. (See LBC[TRC][E][WA], LBC[TRC][G][WA])PAC Levelized Benefit - CostF25F26, F29F30Sum over all measures of PAC benefits less the allocated PAC costs for each measure. For each measure, unit costs (per unit rebates, direct install labor, and direct install materials) are allocated between electric and gas in proportion to the benefits by fuel for that measure. The remaining program costs are allocated to each measure based on each measures share of the total electric and gas benefits. Once allocated to each measure, the remaining program costs are allocated to electric and gas in proportion to the benefits by fuel for that measure. (See LBC[PAC][E][WA], LBC[PAC][G][WA])RIM Levelized Benefit - CostF26F27, F30F31RIM Levelized Benefit RIM Levelized Cost. (Also, see LBC[RIM][E][WA], LBC[RIM][G][WA])Emissions ReductionsElectric ReductionsC35C36:E42E43Units implemented in the year, times the annual emission reduction (due to reduced electricity consumption) for the measure, adjusted for the net-to-gross ratio. (See Emission[E][?])Gas ReductionsF35F36:G42G43Units implemented in the year, times the annual emission reduction (due to reduced gas consumption) for the measure, adjusted for the net-to-gross ratio. (See Emission[G][?])Lifecycle Electric ReductionsC46:E53Units implemented in the year, times the annual emission reduction (due to reduced electricity consumption) for the measure, times the expected useful life of the measure, adjusted for the net-to-gross ratio. (See Emission[E][?])Lifecycle Gas ReductionsF46:G53Units implemented in the year, times the annual emission reduction (due to reduced gas consumption) for the measure, times the expected useful life of the measure, adjusted for the net-to-gross ratio. (See Emission[G][?])Net Impacts Summary by YearAnnual Net kWhC58:C65# of measures installed in the year * Annual kWh reduction per measure * Net-to-gross ratioLifecycle Net kWhD58:D65Total program lifecycle net kWh reductions allocated to years based on the annual kWh for programs installed in the year of concern.Annual Net ThermsE58:E65Total program net therm reductions allocated to years based on the annual kWh for programs installed in the year of concern. (This is an approximation done because of excel column limitations. Subsequent work done for SCE indicates that this approximation could be eliminated in a future revision)Lifecycle Net ThermsF58:F65Total program lifecycle net therm reductions allocated to years based on the annual kWh for programs installed in the year of concern. (This is an approximation done because of excel column limitations. Subsequent work done for SCE indicates that this approximation could be eliminated in a future revision)Net July-Sept kW (OnPeak)C44:C48G58:G65Incremental net average summer peak reductions for measures installed since the 4th quarter of the prior year and until the 3rd quarter of the year of concern. The summer peak impacts are based on the average coincident impact per measure from July through September, adjusted for the Net to-gross ratio. Note that the Net Smr Peak reduction for programs installed for the 4th quarter of the last year of implementation are shown in the spillover row. (See IMP_MO[X])Net Sector NCP (kW)Net Dec-Feb (kW)D44:D48H58:H65Maximum monthly NCP for the year. (See NNCP[t]). Note that the sum of these annual Net NCP values will likely be lower than the Net NCP value shown in the Program Inputs section. As some measures will have maximum reductions in different months, the NCP reductions in any particular month will be lower than the annual NCP reduction (which uses the maximum reduction for each measure, regardless of when that reduction occurs) Sum across all measures of their average December, January, and February coincident peaks. Peak is based on units installed and still effective in the quarters identified for Net July-Sept Peak Coincident peak is defined as the load during the five highest system load hours in each month. (See Equation CP_KW_N_TOT[Wtr]). Value is adjusted for the net to gross ratio.Net CEC (kW)E44:E48I58:I65Total program CEC Peak allocated to years based on the annual kWh for programs installed in the year of concern (F48:F54)User Entered kWAnnual Net kWhJ58:J65H44:H48Sum across all measures installed in the corresponding years, multiplied by their DEER peak grid kW savings adjusted for their net-to-gross ratio. For those cases where peak grid savings are not available, parties should estimate peak reductions consistent with the DEER definition for weather sensitive loads. # of measures installed in the year * Annual kWh reduction per measure * Net-to-gross ratioNet Measure NCP (kW)Lifecycle Net kWhK58:K65I44:I48Sum across all measures of their individual maximum demands in the year, adjusted for net-to-gross ratios. Peak is based on units installed and still effective in the quarters identified for Net July-Sept Peak. (See Net NCP)Total program lifecycle net kWh reductions allocated to years based on the annual kWh for programs installed in the year of concern.Annual Net ThermsJ44:J48Total program net therm reductions allocated to years based on the annual kWh for programs installed in the year of concern. (This is an approximation done because of excel column limitations. Subsequent work done for SCE indicates that this approximation could be eliminated in a future revision)Lifecycle Net ThermsK44:K48Total program lifecycle net therm reductions allocated to years based on the annual kWh for programs installed in the year of concern. (This is an approximation done because of excel column limitations. Subsequent work done for SCE indicates that this approximation could be eliminated in a future revision)Net Impacts by SectorSame information as the Net Impacts Summary section, except segmented by customer sector instead of year of installation. Net CP information is for units in place in the quarters specified above for Net July Sept Peak (kW) (Program Impacts)Net Impacts by CPUC End Use CategoriesSame information as the Net Impacts Summary section, except segmented by end use categories instead of year of installation. Net CP information is for units in place in the quarters specified above for Net July Sept Peak (kW) (Program Impacts) Note that after consultation with the IOUs, the categories were modified slightly. The detailed process categories were abandoned in favor of a single Process; and Domestic Hot Water was made a category distinct from Water Heating.Net Impacts by Climate ZoneSame information as the Net Impacts Summary section, except segmented by location instead of year of installation. Net Average Summer Peak information is for units in place in the 3rd quarter of the 4th year.Persistent reductions in the summer or winterC145:D152Peak reductions tracked, not by the year of installation, but by the amount of peak load reduction that has been installed and not reached the end of its expected useful life in the 3rd of 4th wuarter of each year.Monthly ImpactsAll impacts are based on the devices that would be in place in that month. All measures are assumed to be installed on the first say of the quarter (no ramp-up). (see IMP_MO[x]). Note that the NCP values will not match what is shown in the Program Input section As some measures will have maximum reductions in different months, the NCP reductions in any particular month will be lower than the annual NCP reduction (which uses the maximum reduction for each measure, regardless of when that reduction occurs) Output by Measure Net Impacts by MeasureCols B through ISame information as the Impacts Summary section, except segmented by measure instead of year of installation. CP information is for units in place in 3rd quarter of 4th year.Levelized Benefits less Costsw/ allocated AdminCols L,M,P,QSame information as in the Output Tab for levelized results, but reported by measure.No Allocated Admin TRCCols J,KOnly includes net incremental measure costs in costs. Program costs and other admin costs are not included. (See LBC[TRC][E][NA], LBC[TRC][G][NA])No Allocated Admin - PACCols N,OIncludes per unit costs for 1) rebates, 2) direct installation, and 3) direct install materials. Other rebates and incentives (entered as a lump sum on the Input tab), as well as other program and admin costs are not included. (See LBC[PAC][E][NA], LBC[PAC][G][NA])Benefit Cost RatiosTRC No allocated adminCol RMeasure present value net benefit / present value net cost. Cost is net incremental measure cost.PAC No allocated adminCol SMeasure present value net benefit / present value net cost. Cost is per-unit rebate and incentive costs.TRC w/ allocated adminCol TMeasure present value net benefit / present value net cost. Cost is net incremental measure cost plus allocated admin costs.PAC w/ allocated adminCol UMeasure present value net benefit / present value net cost. Cost is per-unit rebate and incentive costs plus allocated admin costs. Batch Processing A Process Files button is located on the INPUT and CONTROL tabs. These buttons activate Excel Visaul Basic macros that facilitate the separation of calculator input and outputs from the main calculation spreadsheet. Pressing the button calls up the following dialog box  Processing Choice Let me select one file to import. Select this option to check the calculations for one file Process steps are: Open a file selection dialog box for the user to select the file to import (Source file) Open the selected source file, and copy data from the INPUT tab of the input file Past the INPUT data into the Master Calculator file Close the source file Let me select one or more files to process. Select this option to batch process one or more source files that are in the same folder. Batch process refers to importing data from the source file and exporting the results back to that same file. Process steps are: Open a file selection dialog box for the user to select the files to import (Source files). Use the shift key of the control key to select more than one file. Open the selected source file, and copy data from the INPUT tab of the input file Past the INPUT data into the Master Calculator file Calculate the program results for the imported data, and copy the results in the OUTPUT and OUTPUT BY MEASURE tabs back to the source file. If the user has input a suffix (see Names for Processed Files on the dialog box above) then append this suffix to the end of the original source file name and save the combined input and output tabs as the new name. If the user have not entered a suffix, save the combined input and output tabs using the original name (overwrite the original file) Close the source file, and repeat starting at step 2. Batch process the files listed on the Control tab. Select this option to batch process one or more source files that reside in various folders. Batch process refers to importing data from the source file and exporting the results back to that same file. Process steps are: Open the selected source file, using the path and filename information in the CONTROL tab. Copy data from the INPUT tab of the input file Past the INPUT data into the Master Calculator file Calculate the program results for the imported data, and copy the results in the OUTPUT and OUTPUT BY MEASURE tabs back to the source file. If the user has input a suffix (see Names for Processed Files on the dialog box above) then append this suffix to the end of the original source file name and save the combined input and output tabs as the new name. If the user have not entered a suffix, save the combined input and output tabs using the original name (overwrite the original file) Close the source file, and repeat starting at step 1. Just export the current program. Select this option to create a small INPUT and OUTPUT file using the data currently in the Master Calculator. Process steps are: Copy the INPUT data to a new worksheet Copy the OUTPUT and OUTPUT BY MEASURE tabs to the new worksheet. Prompt the user to save the new worksheet with just the input and output data. Input File Rows Select the maximum number of measures allowed in the source spreadsheet Control Tab The control tab is used by the Process Files macro button for batch processing. The user can enter directory path and filename information into this file for unattended batch processing of files in multiple directories. Note that the default is to overwrite these source files with the processed INPUT/OUTPUT file unless a file suffix is specified in the batch processing dialog box. We recommend that you make a duplicate of your files and directories and run the batch processor on these file to avoid accidental loss of the original files. Number of Files to ProcessD11Number of files to process through the Calculator file. Directory PathsC15:C94Directory path for the INPUT files to processFileNamesD15:D94Name of the file to process.Process StatusB15:B94Indicates whether the file is processed successfully Equations Net July-Sept Peak (CP_kW_N_TOT[Smr]) Net July-Sept Peak is an average monthly coincident peak value. The coincident peak is itself, the average of the loads during the five highest PG&E system loads for the month. These average peak loads are then averaged for July through September. Net refers to the peak estimate being reduced by the Net-to-Gross ratio. This peak load estimate is derived in two ways, depending on whether hourly end use data or H-factor information is used for the end use shape.  EMBED Equation.3  Where IN_CM,Q = # of cumulative units of measure M installed by Quarter Q PG&E: 3rd Qtr 2011 SDG&E: 3rd Qtr 2009 SCE: 4th Qtr 2008 SoCalGas: 3rd Qtr 2009 Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q For end use shapes with hourly loads:  EMBED Equation.3  Where kWh_A = Annual kWh reduction for measure M NTGM = Net to-Gross ratio for measure M m = months 7, 8 and 9 CP_kW_FactorS,m = Coincident peak factor for end use shape S (corresponding to measure M) and month m. CP_kW_FactorS,m = Average peak load from month m divided by total annual end use load. The average peak load for shape S is the average end use load during the five highest PG&E system loads for the month adjusted to the chronology of the hourly end use load shapes. The residential hourly end use load shapes are from 1994, adjusted to match the chronology for 1999 by adding one day at the beginning of the shapes. 1999 is used for the base year because the hourly generation market price shape is based on 1999. The 1994 PG&E system load indices were similarly adjusted by adding 24 to each index value.  EMBED Equation.3  For end use shapes that use TOU-factors:  EMBED Equation.3  Where kW_SmrM = Summer peak kW reduction for measure M. For measures that have a kW demand scaler, this value is a user input. For measures that have a kWh demand scaler, this value equals the Summer peak kW TOU factor times the annual kWh reduction for the measure. 1 = Coincidence factor (1 by assumption) NTGM = Net-to-Gross ratio for measure M Net Dec-Feb Peak (CP_kW_N_TOT[Wtr]) Net Dec-Feb Peak is an average monthly coincident peak value. It is calculated the same as the Net July-Sept Peak, except that it used December, January, and February peaks, rather than July September.  EMBED Equation.3  Where IN_CM,Q = # of cumulative units of measure M installed by Quarter Q PG&E: 3rd Qtr 2011 SDG&E: 3rd Qtr 2009 SCE: 4th Qtr 2008 SoCalGas: 3rd Qtr 2009 Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q For end use shapes with hourly loads:  EMBED Equation.3  Where kWh_A = Annual kWh reduction for measure M NTGM = Net to-Gross ratio for measure M m = months 12, 1, and 2 CP_kW_FactorS,m = Coincident peak factor for end use shape S (corresponding to measure M) and month m. For end use shapes that use H-factors:  EMBED Equation.3  Where kW_WtrM = Winter peak kW reduction for measure M. 1 = Coincidence factor (1 by assumption) NTGM = Net-to-Gross ratio for measure M Noncoincident Peak (Net NCP) For End Use shapes with hourly loads: NCP_FM.m = Max normalized end use hourly load in month m Normalized end use hourly loads sum to 1.0 over the 8760 observations. Net NCP = (M [(IN_CM,Q - Exp_CM,Q) * kWh_AM * NTGM * Maxm = 1 to 12(NCP_FM,m) ] where IN_CM,Q = # of cumulative units of measure M installed by Quarter Q Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q Q = PG&E: 3rd Qtr 2011 SDG&E: 3rd Qtr 2009 SCE: 4th Qtr 2008 SoCalGas: 3rd Qtr 2009 kWh_A = Annual kWh reduction for the measure NTGM = Net to-Gross ratio for measure M NCP_FM.m = Noincident Peak factor for measure M in month m. M = Measure m = month S = End Use shape For end use shapes that use H-factors: NCP_FM.m = kW_SmrM,*Max (kW H-factor, for summer or winter) * NTGM Where Summer is April through October, Winter is the other months. Noncoincident Peak by Year (NNCP[t]) For End Use shapes with hourly loads:  EMBED Equation.3  Where INM,Q = # of incremental units implemented in quarter Q for measure M T = Year of implementation For end use shapes that use H-factors:  EMBED Equation.3 Where kW_H_Factor = H-factor by TOU period for capacity for the matching season. kW_Smr = User input summer peak kW reduction for one unit. CEC Peak (Net CEC) Net CEC (KW) = (M [(IN_CM,Q - Exp_CM,Q) * kWh_AM * NTGM * (CEC_F) / 1000] where IN_CM,Q = # of cumulative units of measure M installed by Quarter Q Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q NTGM = Net to-Gross ratio for measure M CEC_F = 0.217 (value prescribed by CEC) Annual Net kWh (Annual_kWh) Annual_kWh = (M (Q (INM,Q * kWh_AM * NTGM ) Where INM,Q = # of incremental units implemented in quarter Q for measure M. Lifecycle Net kWh (Lifecycle_kWh) Lifecycle_kWh = (M (Q (INM,Q * kWh_AM * NTGM * LM) Where LM = End use measure life in years. Annual Net Therms (Annual_Therms) For PG&, SoCal and SDG&E: Annual_Therms = (M (Q (INM,Q * Th_AM * NTGM ) Where Th_AM = Annual therm reductions for measure M Q = All quarters in which units are implemented under the program being evaluated For SCE Annual_Therms = (M [(IN_CM,Q - Exp_CM,Q) * Th_AM * NTGM * (CEC_F) / 1000] where IN_CM,Q = # of cumulative units of measure M installed by Quarter Q Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q Q = SCE: 4th Qtr 2008 Lifecycle Net Therms (Lifecycle_Therms) Lifecycle_kWh = (M (Q (INM,Q * Th_AM * NTGM * LM) Where LM = End use measure life in years. Cost Effectiveness (Lifecycle Present Value Dollars) Cost TRC Cost (TOTCOSTTRC) TOTCostTRC = Total Program Budget + IMC_PV TOT_INC[PV] (Note that TOT_INC[PV] is subtracted from the TotCostTRC because TOT_INC[PV] is included in Total Program Budget. Where Program Budget = Sum of user inputs for Administrative, Marketing/Outreach, Direct Implementation (including per measure rebate payments and direct install labor and amterials), EM&V, and Performance Award IMC_PV = Net incremental measure cost (present value)  EMBED Equation.3  PCM = Incremental cost for Measure M. INM,Q = # of incremental of measures implemented in quarter Q. NTGM = Net to-Gross ratio for measure M Q = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas. TOT_INC[PV] = Present Value of rebate and incentive payments provided to participants TOT_INC[Nom] = Sum of rebate and incentive payments provided to participants  EMBED Equation.3   EMBED Equation.3  INC = User input value for lump sum incentive costs RebateM = Rebate costs for Measure M. Q = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas. DI_LM = Direct install labor incentive costs for Measure M. DI_MM = Direct install materials incentive costs for Measure M. PAC Cost (TotCostPAC) TotCostPAC = Total Program Budget TOT_INC[Nom] + TOT_INC[PV] Where TOT_INC[PV] = Present Value of rebate and incentive payments provided to participants RIM Cost (TotCostRIM)  EMBED Equation.3  Where Q = Number of quarters of implementation for this program. PG&E uses a maximum of 5 yrs; SDG&E, 3 yrs; SCE, 7 years.  EMBED Equation.3  Where y = Year of implementation y = Year counter beginning in the year of implementation LM = Measure life in years. Lifecycle Benefit Electric TRC Benefits (NetPVBenTOT[E])  EMBED Equation.3  Where NTGM = Net to-Gross ratio for measure M  EMBED Equation.3  r = annual discount rate Q = quarter, beginning in January Q = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas. INM,Q = # of incremental of measures implemented in quarter Q PV[Gen]M,Q = Present value of avoided generation costs for measure M, corresponding to the climate zone for measure M, installed by quarter Q DmdScaler = Demand Scaler. Equals kWh_AM for those measures that are based on hourly shapes of use TOU demand factors that are normalized to energy (like PG&E residential). Equals Summer Peak kW (input column R) for other measures. PV[TD]M,Q = Present value of avoided T&D costs for measure M, corresponding to the climate zone for measure M, installed by quarter Q For hourly end use shapes:  EMBED Equation.3  L = Measure life in years h = hours in the quarter, Q t = year corresponding to quarter Q plus n-1 years. kWEU,h,CZ = Normalized load for end use EU during hour h in climate zone CZ EU = End use selected to correspond to measure M CZ = Climate zone specified for the measures M AC[Gen]h,t = Avoided cost of generation ($/kWh) in the climate zone corresponding to the measure for hour h in year t. This value includes environmental costs.  EMBED Equation.3  AC[TD]h,t,CZ = Avoided cost of T&D ($/kWh) in the climate zone corresponding to the measure for hour h in year t. For H-factor end use shapes.  EMBED Equation.3 where Q = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas.  EMBED Equation.3  Trunc = The truncation function to round down to the nearest integer value. The first term calculates the NPV for all whole quarters of measure life. The second term captures the value for any remaining fractional quarters of life. TOU = Time of use period corresponding to the quarter. The three summer periods are used for quarters 2 and 3. The two winter TOU periods are used for quarters 1 and 4. kWM = Summer on-peak kW reduction for the measure. HF[kWh]EU,TOU = H-factor for energy share for the EU for the TOU period AC[Gen]TOU = Simple average of implied hourly net generation avoided costs in the climate zone for the measure during the TOU period in year t. t = year corresponding to quarter Q plus n-1 yearsn. TOUCorrU,S = [1 + (AC TOU Correction factor for utility u 1) * percent of the measure that qualifies for the correction factor]. The AC TOU correction factor varies for residential and non-residential sectors s. If a measure has an end use that does not qualify for the AC TOU correction factor, TOUCorr is set to 1.0. See  REF _Ref141979025 \h Table 7 for AC TOU Correction factors.  EMBED Equation.3  Trunc = The truncation function to round down to the nearest integer value. The first term calculates the NPV for all whole quarters of measure life. The second term captures the value for any remaining fractional quarters of life AC[TD]TOU,CZ,t = Sum of T&D avoided costs in climate zone for the measure during the TOU period in year t. HF[kWh]EU,TOU = H-factor for energy share for the EU for the TOU period Gas TRC Benefits (NetPVBenTOT[G])  EMBED Equation.3  Where NTGM = Net to-Gross ratio for measure M  EMBED Equation.3  R = annual discount rate Q = quarter, beginning in January n = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas. INM,Q = # of incremental of measures implemented in quarter Q Th_AM = Annual gas reduction (in therms) for measure M. PV[Gas]M,Q = Present value of avoided gas costs for measure M installed by quarter Q. Expressed as $ per annual Therm reduction. Includes procurement, environmental and T&D avoided costs.  EMBED Equation.3  AC[GasC]Q,t = Gas commodity avoided cost in year t. Cost is the average of the monthly commodity costs in the quarter. AC[GasTD]Q,t,S = Gas T&D avoided cost for quarter Q in year t, based on gas seasonal usage pattern S. T&D benefits are uniform $/Therm values for the winter months (Nov through Mar). Therefore a gas measure that has all of its reductions in the summer would receive no T&D avoided cost value. A measure with all of its savings in the winter would receive full TD avoided cost value. A measure with year round savings would have the TD $/therm avoided cost reduced by a factor of 2 to reflect that fact that only half of the therm reductions (the half that occurs during the winter) would result in T&D avoided costs. Levelized Cost and Benefit Discounted Electric Reductions (kWhD[N]) kWhD[G] = Discounted avoided kWh Gross. kWhD[N] = Discounted avoided kWh Net.  EMBED Equation.3   EMBED Equation.3  INM,Q,CZ = # of incremental of measures implemented in quarter Q. kWh_AM = Annual kWh reduction for measure M. Q = Number of quarters of implementation. 20 for PG&E, 28 for SCE, and 12 for SDG&E and SoCalGas. PV(r,L,-1) = The uniform series present worth factor, using a discount rate of r and L number of years. L = Measure life in years. kWhD[N]M,CZ = kWhD[G]M,CZ * NTGM kWhD[N] = SM,CZ (kWhD[G]M,CZ * NTGM) NTGM = Netto-Gross ratio for measure M. Discounted Gas Reductions (ThD[N]) ThD[G] = Discounted avoided therms Gross. ThD[N] = Discounted avoided therms Net.  EMBED Equation.3   EMBED Equation.3  Th_AM = Annual gas reduction (in therms) for measure M. N = Number of quarters of implementation ThD[N]M,CZ = ThD[G]M,CZ * NTGM NTGM = Netto-Gross ratio for measure M. Levelized Cost TRC Levelized Cost ($/kWh) (LC[TRC][E]) LC[TRC][E] = LB[TRC][E] LBC[TRC][E] Where LB[TRC][E] = Levelized benefits under the TRC test for electric (defined later) LBC[TRC][E] = Levelized benefit cost under the TRC test for electric (defined later) PAC Levelized Cost ($/kWh) (LC[PAC][E]) LC[PAC][E] = LB[TRC][E] LBC[PAC][E] Where LB[TRC][E] = Levelized benefits for electric (PAC and TRC benefits are the same) LBC[PAC][E] = Levelized benefit cost under the TRC test for electric (defined later) RIM Levelized Cost ($/kWh) (LC[RIM][E])  EMBED Equation.3  TRC Levelized Cost ($/Th) (LC[TRC][G]) LC[TRC][G] = LB[TRC][G] LBC[TRC][G] Where LB[TRC][G] = Levelized benefits under the TRC test for gas (defined later) LBC[TRC][G] = Levelized benefit cost under the TRC test for gas (defined later) PAC Levelized Cost ($/Th) (LC[PAC[G]) LC[PAC][G] = LB[TRC][G] LBC[PAC][G] Where LB[TRC][G] = Levelized benefits for gas (PAC and TRC benefits are the same) LBC[PAC][G] = Levelized benefit cost under the TRC test for gas (defined later) RIM Levelized Cost ($/Th) (LC[RIM][G])  EMBED Equation.3  Where ThD[N] = Discounted lifecycle therm reductions, adjusted for the Net-to-Gross ratio. Levelized Benefits TRC Levelized Benefits ($/kWh) (LB[TRC][E]) Values are the same for all cost tests. LB[TRC][E] = NetPVBenTOT[E] / kWhD[N] LB[PAC][E] = NetPVBenTOT[E] / kWhD[N] LB[RIM][E] = NetPVBenTOT[E] / kWhD[N] TRC Levelized Benefits ($/Therm) (LB[TRC][G]) Values are the same for all cost tests. LB[TRC][G] = NetPVBenTOT[G] / ThD[N] LB[PAC][G] = NetPVBenTOT[G] / ThD[N] LB[RIM][G] = NetPVBenTOT[G] / ThD[N] Levelized Benefit Cost Levelized Benefits Costs: Electric, TRC Test, No Admin Costs. (LBC[TRC][E][NA])  EMBED Equation.3  Where NA = No Admin. Indicates that the metric does not include admin costs. EAllocM = Electric allocation for measure M. = NetPVBen[E]M / (NetPVBen[E]M + NetPVBen[G]M) IMC_PV = Net incremental measure cost (present value). This was defined in the Cost section. Levelized Benefits Costs: Gas, TRC Test, No Admin Costs. (LBC[TRC][G][NA])  EMBED Equation.3  Levelized Benefits Costs: Electric, TRC Test, with Admin Costs. (LBC[TRC][E][WA])  EMBED Equation.3  Where WA = With Admin. Indicates that the metric does include admin costs. Admin[TRC] = Total Program Costs excluding rebates and incentives MAllocM,CZ = Measure allocation.  EMBED Equation.3  Levelized Gas Benefits Costs: Gas, TRC Test, with Admin Costs. (LBC[TRC][G][WA])  EMBED Equation.3  Levelized Benefits Costs: Electric, PAC Test, No Admin Costs. (LBC[PAC][E][NA])  EMBED Equation.3  Where UnitIncM,CZ = Present value Per unit Rebate + per unit direct install labor + per unit direct install materials. Discounting is based on installation schedule. (see TOT_INC for discounting details) Levelized Benefits Costs: Gas, PAC Test, No Admin Costs. (LBC[PAC][G][NA])  EMBED Equation.3  Levelized Benefits Costs: Electric, PAC Test, with Admin Costs. (LBC[RIM][E][WA])  EMBED Equation.3  Where Admin[PAC] = Total Program Costs less the sum of all UnitIncM,CZ (this is done to avoid double counting, as those per-unit costs are included in the no admin costs case) Levelized Gas Benefits Costs: Gas, PAC Test, with Admin Costs. (LBC[RIM][G][WA])  EMBED Equation.3  Emissions Reductions Electric Reductions: CO2 tons per year (Emission[E][CO2])  EMBED Equation.3  Where y = year of consideration. 2006 = 1. Total Annual used for years 2008 through the end of the implementation period. Q = Quarter of the year. Jan-Mar 2006 = 1. INM,Q = # of incremental of measures implemented in quarter Q. NTGM = Netto-Gross ratio for measure M. ER[CO2]M = Emission rate of CO2 in tons per kWh of measure M. NOX and PM-10 equations are the same. Just replace [CO2] with the appropriate indicator. Note that CO2 emission rate is in tons per kWh. NOX and PM-10 are in pounds per kWh. Gas Reductions: CO2 tons per year (Emission[G][CO2])  EMBED Equation.3  Where y = year of consideration. 2006 = 1. Total Annual used for years 2008 through the end of the implementation period. Q = Quarter of the year. Jan-Mar 2006 = 1. INM,Q = # of incremental of measures implemented in quarter Q. NTGM = Netto-Gross ratio for measure M. ER[CO2]GCT = Emission rate of CO2 in tons per therm, based on the gas combustion type (GCT) specified on the input sheet for the measure. NOX and PM-10 equations are the same. Just replace [CO2] with the appropriate indicator. Note that CO2 emission rate is in tons per Therm. NOX and PM-10 are in pounds per Therm. Monthly Impacts (IMP_MO[X], IMP_MO[Th]) For CP, NCP, and monthly kWh.  EMBED Equation.3  Where IMP_MO[X] = Monthly impact for metric X. Metrics can be CP, NCP, kWh kWh_AM = Annual kWh reduction for measure M. NTGM = Netto-Gross ratio for measure M. IMP_U[X]M.m = Per unit impact for metric X. Value is normalized to total annual kWh reductions. IN_CM,Q = # of cumulative units of measure M installed by Quarter Q PG&E: 3rd Qtr 2011 SDG&E: 3rd Qtr 2009 SCE: 4th Qtr 2008 SoCalGas: 3rd Qtr 2009 Exp_CM,Q = # of units of measure M, installed under this program that have reached the end of their useful life prior to Quarter Q M = Measure m = Month of the year (1 12) For Monthly Therms  EMBED Equation.3  Where IMP_U[Th]M,m = Per unit impact for therms. Value is normalized to total annual kWh reductions, so the sum of across the 12 months = 1.0. Sector and End Use Shape Combinations Table  SEQ Table \* ARABIC 1: PG&E Non-Res H-Factor (TOU) based shapes. Sector Name is at the top of the column.  Table  SEQ Table \* ARABIC 2: PG&E Non-Res Hourly Load based shapes. Sector name is at the top of the column  Table  SEQ Table \* ARABIC 3: PG&E Residential Shapes  Table  SEQ Table \* ARABIC 4: SCE End Use Shapes (Sectors are in Bold)  Table  SEQ Table \* ARABIC 5: SDG&E End Use Measures (Not limited by sector in the spreadsheet)  Table  SEQ Table \* ARABIC 6: SoCalGas Shapes  Table  SEQ Table \* ARABIC 7: AC TOU Correction Factors PG&ESCESDG&ESoCalGasResidential1.1711.2021.2761.202Non-Residential1.085+/04WXY]^_`a} ~  ȾܫzzaL(HhA Fhoh~og0JmHnHu1jHhA Fhoh~og0JUmHnHujh5<Uh5<5>*OJQJ^Jh5<h5<5>*OJQJ^Jh5<h\*h[0%h=/h~ogcHdhdhdh9 FHhFh/pHh Fh:lHh8 Fhr h;glHh Fh:lHh7 Fhr h7s%h"r+h=/5`a~   * H ! 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?3"`?2rK$ )aNu;`!FK$ )a1PLxtxcdd``> @c112BYL%bpu?@ABCDEFGHIJKLMNOPQRSTUVWXYZ[\]^_`abcdefghijklmnopqrstuvwxyz{|}~      !"#$%&'()*+,-./0123456789:;<=>?@ABCDEFGHIJKLMNOPQRSTUVWXYZ[\]^_`abcdefghijklmnopqrstuvwxyz{|}~      !"#$%&'()*+,-./0123456789:;<=>EHhIJKLMNOPRQSTUVWXYZ[\]^_`abcdefgijklmnopqrstuvwyxz{|~}Root Entry FPgXG@|Data WordDocumentObjectPoolnfXPgX_1178623805FnfXnfXOle CompObjfObjInfo !"%()*+.12347:;>ABCDEFILMNOPQTWXYZ]`abcdehklmnoruvwx{~ FMicrosoft Equation 3.0 DS Equation Equation.39qdX | CP_KW_N_TOT[Smr]=CP_KW_N[Smr] MM " *IN_C M.Q "Exp_CEquation Native "_1178623408 FnfXnfXOle  CompObj f M,Q () FMicrosoft Equation 3.0 DS Equation Equation.39qdm CP_KW_N[Smr] M =kWh_A M *NTG M *CPObjInfo Equation Native  "_1172588228FnfXnfXOle _kW_Factor S,m ()3 m " FMicrosoft Equation 3.0 DS Equation Equation.39q).8m CP_KW_Factor S,m =ECompObjfObjInfoEquation Native J_1178622494FnfXVqfXULoad S,hrhr m =15 " 5EULoad S,hrhr=18760 " FMicrosoft Equation 3.0 DS Equation Equation.39qOle CompObjfObjInfoEquation Native  dY CP_KW_N[Smr] M =kW_Smr M *1*NTG M FMicrosoft Equation 3.0 DS Equation Equation.39qd_ CP_KW_N_1178624372'FVqfXVqfXOle #CompObj$fObjInfo&Equation Native '"_1178622659"FVqfXVqfXOle ,CompObj -f_TOT[Wtr]=CP_KW_N[Wtr] MM " *IN_C M.Q "Exp_C M,Q () FMicrosoft Equation 3.0 DS Equation Equation.39qObjInfo!/Equation Native 0"_1178622691$FVqfXVqfXOle 5dh CP_KW_N[Wtr] M =kWh_A M *NTG M *CP_kW_Factor S,m ()3 m " FMicrosoft Equation 3.0 DS Equation Equation.39qCompObj#%6fObjInfo&8Equation Native 9_1178625486)FVqfXsfXd($ CP_KW_N[Wtr] M =kW_Wtr M *1*NTG M FMicrosoft Equation 3.0 DS Equation Equation.39qOle <CompObj(*=fObjInfo+?Equation Native @don NNCP[t]=IN M,Q ()*Max m=1to12 NCP_F M,m () Q=14(foryrt) " *NTG M *kWh_A M () M "_1178625523 T.FsfXsfXOle GCompObj-/HfObjInfo0J FMicrosoft Equation 3.0 DS Equation Equation.39qdw+t NNCP[t]=IN M ()*Max by_TOU kW_H_Factor M () Q=14(foryrt) " *NTGEquation Native K_1217744647c3FsfXsfXOle RCompObj24Sf M *kW_Smr M () M " FMicrosoft Equation 3.0 DS Equation Equation.39q& M } IMC_PV  = M " IN MObjInfo5UEquation Native V(_12177453828FsfXsfXOle [,Q *PC M *NTG M 1+r4() QQ=1Q' " [] FMicrosoft Equation 3.0 DS Equation Equation.39q&uhk} TOT_INCCompObj79\fObjInfo:^Equation Native __1178695404=F8vfX8vfX[PV]  =INC+ M " IN M,Q *Rebate M +DI_L M +DI_M M ()1+r4() QQ=1Q' " [] FMicrosoft Equation 3.0 DS EqOle fCompObj<>gfObjInfo?iEquation Native jauation Equation.39qdE_, TOT_INC[Nom]  =INC+ M " IN M,Q *Rebate M +DI_L M +DI_M M () Q=1Q' " []_1179036369BFxfXxfXOle pCompObjACqfObjInfoDs FMicrosoft Equation 3.0 DS Equation Equation.39qd TotCostRIM=TotCostPAC+BillDiscount M,yy=1Q'/4 " M "Equation Native t_1178695569;JGFxfXxfXOle yCompObjFHzf FMicrosoft Equation 3.0 DS Equation Equation.39qdck BillDiscount M,y =kWh_A MQ=14 " *ObjInfoI|Equation Native }_1178699027|LFxfXzfXOle IN M,Q ()*Rate M,y' (1+r) yy'=1L M " [] FMicrosoft Equation 3.0 DS Equation Equation.39qd0D NetPVBeCompObjKMfObjInfoNEquation Native _12177454656^QFzfXzfXnTOT[E]  =PVBen[E] M *NTG M () M " FMicrosoft Equation 3.0 DS Equation Equation.39q&Ž^} PVBen[EOle CompObjPRfObjInfoSEquation Native ] M =IN M,Q *kWh_A M *PV[Gen] M,Q +DmdScaler M *PV[TD] M,Q ()1+r4() QQ=1Q' " FMicrosoft Equation 3.0 DS Eq_1178699379EmVFzfXFfXOle CompObjUWfObjInfoXuation Equation.39qd'm PV[Gen] M,Q =kW EU,h *AC[Gen] h,t,CZ () h " (1+r4) nn=1L*4 "Equation Native C_1178699597[FFfXFfXOle CompObjZ\f FMicrosoft Equation 3.0 DS Equation Equation.39qd0t PV[TD] M,Q =kW EU,h *AC[TD] h,t,CZ () h " (1+r4ObjInfo]Equation Native ;_1217746685`FFfXfXOle ) nn=1L*4 " FMicrosoft Equation 3.0 DS Equation Equation.39q&hk} PVBen[E] M =IN M,Q,C Z*kWh_A M *PVCompObj_afObjInfobEquation Native _1217748346OweFfXfX[Gen] M,Q *TOUCorr U,S +DmdScaler M *PV[Cap] M,Q,CZ ()1+r4() QQ=1Q' " FMicrosoft Equation 3.0 DS Equation Equation.39qOle CompObjdffObjInfogEquation Native @&$hkJ PV[Gen] M,Q =HF[kWh] EU,TOU *AC[Gen] TOU,t () TOU " (1+r4) nn=1Trunc(L*4,0) " +L*4"Trunc(L*4,0)()HF[kWh] EU,TOU *AC[Gen] TOU,t () TOU " (1+r4) n [] n=Trunc(L*4,0)+1  FMicrosoft Equation 3.0 DS Eq_1217748407jFfXfXOle CompObjikfObjInfoluation Equation.39q&a/ PV[Cap] M,Q =HF[kW] EU,TOU *AC[TD] TOU,t () TOU " (1+r4) n [] n=1Trunc(LEquation Native _1178701356YroFfXfXOle CompObjnpf*4,0) " +(L*4"Trunc(L*4,0))HF[kW] EU,TOU *AC[TD] TOU,t () TOU " (1+r4) n [] n=Trunc(L*4,0)+1 FMicrosoft Equation 3.0 DS Equation Equation.39qd_ NetPVBenTOT[G]  =PVBen[G] M *NTG M () M "ObjInfoqEquation Native _1178701373tFfXp9fXOle CompObjsufObjInfovEquation Native L_1217748483hyFp9fXpfX"! FMicrosoft Equation 3.0 DS Equation Equation.39qd0`4 PVBen[G] M =1+r4()IN M,Q *Th_A M *PV[Gas] M,Q (1+r4) QQ=1n " FMicrosoft Equation 3.0 DS Equation Equation.39q&¬Pjg PV[Gas] M,Q =AC[GasC] Q,t +AC[GaOle CompObjxzfObjInfo{Equation Native sTD] Q,t,S ()(1+r) nn=1Trunc(L*4,0) " +(L*4"Trunc(L*4,0))AC[GasC] Q,t +AC[GasTD] Q,t,S ()(1+r) n [] n=Trunc(L*4,0)+1 FMicrosoft Equation 3.0 DS Equation Equation.39qdwg kWhD[G]=kWhD[G] M [] M "_1178695648~FpfXpfXOle CompObj}fObjInfoEquation Native _1217748627F`fX`fXOle CompObjf  !"%()*+,/234569<=>?@CFGHIJKNQRSTUVY\]^_`cfghijmpqrstux{|}~ FMicrosoft Equation 3.0 DS Equation Equation.39q&k  kWhD[G] M =IN M,Q *kWh_A M *PV(r,L,"1)1+r4() ObjInfoEquation Native 5_1174120934F`fX`fXOle  QQ=1Q' " [] FMicrosoft Equation 3.0 DS Equation Equation.39qY€!d ThD[G]  =ThD[G] M,CZM,CZ "CompObj fObjInfo Equation Native  _1217748626F`fX`fXOle CompObjfObjInfoEquation Native 1 FMicrosoft Equation 3.0 DS Equation Equation.39q&{} ThD[G] M,CZ =IN M,Q,CZ *Th_A M *PV(r,L,"1)1+r4() QQ=1n " FMicrosoft Equation 3.0 DS Equation Equation.39qdJw LC[RIM][E]=TotCostRIM*NetPVBenTOT[E_1178703547,F`fX`fXOle CompObjfObjInfoEquation Native f_1178703780F`fX`efXOle #CompObj$f]NetPVBenTOT[E]+NetPVBenTOT[G]()kWhD[N] FMicrosoft Equation 3.0 DS Equation Equation.39qdFy LC[RIM]ObjInfo&Equation Native 'b_1178707386F`efX`efXOle -[G]=TotCostRIM*NetPVBenTOT[G]NetPVBenTOT[E]+NetPVBenTOT[G]()ThD[N] FMicrosoft Equation 3.0 DS Equation Equation.39qCompObj.fObjInfo0Equation Native 1Q_1178707552F`efX`efXd5v| LBC[TRC][E][NA]  =NetPVBen[E] M "IMC_PV M *EAlloc M ()kWhD[N] MM "Ole 7CompObj8fObjInfo:Equation Native ;` FMicrosoft Equation 3.0 DS Equation Equation.39qdDm LBC[TRC][G][NA]  =NetPVBen[G] M "IMC_N M *1"EAlloc M ()()ThD[N] MM " FMicrosoft Equation 3.0 DS Equation Equation.39qdm& LBC[TRC][E][WA]  =LBC[TRC][E][NA]  "_1178707611F`efX`efXOle ACompObjBfObjInfoDEquation Native E_1178707686F`efX`fXOle LCompObjMfAdmin[TRC]*EAlloc M *MAlloc M ()kWhD[N] MM " FMicrosoft Equation 3.0 DS Equation Equation.39qObjInfoOEquation Native P_1178707773F`fX`fXOle Wdy(hD LBC[TRC][G][WA]  =LBC[TRC][G][NA]  "Admin[TRC]*(1"EAlloc M )*MAlloc M ()ThD[N] MM "CompObjXfObjInfoZEquation Native [U_1178707860F`fX`fX FMicrosoft Equation 3.0 DS Equation Equation.39qd9' LBC[PAC][E][NA]  =NetPVBen[E] M "UnitInc M *EAlloc M ()kWhD[N] MM " FMicrosoft Equation 3.0 DS Equation Equation.39qdLȋ LBC[PAC][G][NA]  =NetPVBen[G] M "UOle aCompObjbfObjInfodEquation Native ehnitInc M *1"EAlloc M ()()ThD[N] MM " FMicrosoft Equation 3.0 DS Equation Equation.39qdm$ LBC[PAC27$37X/\!(?71;!2Bu`RX _}|uTjL¨E |;Nt?` rĞx? 0Cq`E6 ,@sC2sSRsly  s3$@C%@|(7Cojq(zo ( .G,"p`dl&= 1Xe"Xܐ@峂\ 6L|' Xy@\8"~dl؀,PkFat14v[brI~,l;A~@|G)7 Zq)pa%lLLJ% ) s:@ |b@f~Dd Tb  c $A? ?3"`?2L$z4ZOW;`!L$z4ZOW8 x.,XJxxcdd`` @c112BYL%bpu @c112BYL%bpuߨk@X8_FďIWC[AտU.*? wq_Bno _~!qm R4 ZjqK6.] `pYĤ\Y\ t0.?1"2Dd b  c $A? ?3"`?2|QjfGwy`X;`!PQjfGwy`H* wBdxcdd``^$d@9`,&FF(`TI偖 A?dZ 'zjx|K2B* Rjvf1 @201W&0;n׮RČ`u ,@RF\5 Jby`Z  /&@f?( DeA,a k 2n`ꆟL@*BL Ps M-VK-WMc ν2 =FwMT~ 30O}|aT*n.u*l@[brI~TQa s'4̦2_{ ,Ӆ@8TD1M(xe [a|=Xb9ߏDd kTb  c $A? ?3"`?2Fc q72_;`!Fc q72_8 5+XJyxcdd`` @c112BYL%bpuc%0zAf9#ZkZy7f}-(0cp%Mf#5!HeJiC{>\^9Ԥq Y'( XW}/_cp0`I)͇Iیـ?j "&V+OHͷ(߅ja|mkEGW}K3VCsqTqnS?gM$#~ sY ^QW.5w~X+8j\X?bBn*jSN!3͝ߠy)\N6;L%cllE.hzͧ7砤q:awo+أOPq Jc7xfU+bzA#i'Mw'2ͻxD%[YIc L t]G~~ů] j;9k5T&FsVwXJy:%[m1s㚡 +0TM;.?%[Z9=2Bw+ ɟ97Dd ,b   c $A ? ?3"`? 2˴,":1;`!˴,": 1PM`\xڥkQϽ3&`X[+ԦiVA X M$q$]hAН(]HK7q!Z(m>T.sws3C i^k z#lc.I=m~ڠ(c=,FjP(;WJ*cj5ǤT*= 8jޘcp00C2H%Ia~e*2n:T%[w,jVazݣ⃫)X]?i+2#.xYS"Wȟ Wtx%{T!J7~C/_l Q-]UgVkmrc/YZ[& ]nQ |/O*&cvҩ3NT|~Md4lmv뫖 ?}YXڏ tBУ}8K]WQ]i#2] [R|M⤥xAGRV:6ǎz *.3> r{wP3~@>gv 9wqy/rR .}Dd b  c $A? ?3"`?23cүhyZ6L`!3cүhyZ6`@ Ho*PVixڥMkAǟK5MT^EmA)6j[]hZm qՃA x CJ]mh҅y3 !lpadp<ڃ62*/Y.mP%CyF:MZ#sPT LLFn$xQYFK(I""5 N+/]k64zͯ.|xMwQ/ Mϳ?=f<(@0֓<%H~V;=v^L )X5<֜E"g'tVk~ݫ hmp;$wk]_ѷ>wRItyn;rϿSP.ΐ&ZB$Wq.lf\V|,N2p[|m nc,77'*գ~h=?V"k|%0r/f&;0.qs@+=^&\hfWDd `b  c $A? ?3"`?25Ij gCL`! 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