2025 Nonresidential
Alterations:
Reach Code Study
Prepared by:
TRC Companies:
Lucy Albin, Shannenia Sumawan,
Avani Goyal, Farhad Farahmand
Prepared for:
Amy Discher, Southern California
Edison
Revision: 1.0
Last modified: 2025/07/07
2025 Nonresidential Alterations Reach Code Study 1
2025/07/07
Summary of Revisions
Date Description Reference (page or section)
7/7//2025 Original Release N/A
Legal Notice
This report was prepared by
Southern California Edison and
funded by the California utility
customers under the auspices of
the California Public Utilities
Commission.
Copyright 2025, Southern
California Edison. All rights
reserved, except that this
document may be used, copied,
and distributed without
modification.
Neither SCE nor any of its
employees makes any warranty,
express or implied; or assumes
any legal liability or responsibility
for the accuracy, completeness or
usefulness of any data,
information, method, product,
policy or process disclosed in this
document; or represents that its
use will not infringe any privately-
owned rights including, but not
limited to, patents, trademarks or
copyrights.
2025 Nonresidential Alterations Reach Code Study 2
2025/07/07
Acronym List
B/C – Benefit-to-Cost Ratio
CBECC - California Building
Energy Code Compliance
CBSC - California Building
Standards Commission
CEC - California Energy
Commission
CPAU – City of Palo Alto
Utilities
CZ – Climate Zone
GHG - Greenhouse Gas
HP – Heat Pump
HVAC – Heating,
Ventilation, and Air
Conditioning (equipment)
IOU – Investor-Owned
Utility
kWh – Kilowatt Hour
LSC – Long-term
Systemwide Cost
MF – Mixed-Fuel
NPV – Net Present Value
POU – Publicly Owned
Utility
PG&E – Pacific Gas &
Electric (utility)
PV - Solar Photovoltaic
RTU – Rooftop Unit
(equipment)
SCE – Southern California
Edison (utility)
SCG – Southern California
Gas (utility)
SDG&E – San Diego Gas &
Electric (utility)
SMUD – Sacramento
Municipal Utility District
SZAC – Single Zone Air
Conditioner
SZHP – Single Zone Heat
Pump
Title 24 – California Code of
Regulations Title 24, Part 6
2025 Nonresidential Alterations Reach Code Study 1
2025/07/07
Table of Contents
Executive Summary............................................................................................................... 4 1 Introduction..................................................................................................................... 5 2 Methodology and Assumptions ................................................................... ..................6
2.1 Cost-Effectiveness ..................................................................................................... 6
2.1.1 Benefits ............................................................................................................... 6
2.1.2 Costs ................................................................................................................... 6
2.1.3 Metrics................................................................................................................. 7
2.1.4 Utility Rates ......................................................................................................... 7
2.2 Greenhouse Gas Emissions................................................................... .................... 9 3 Prototypes, Measure Packages, and Costs ................................................................ 10
3.1 Prior Reach Code Study Research............................................................................10
3.2 Prototype Characteristics ..........................................................................................10
3.3 Measure Definitions and Costs..................................................................................13
3.3.1 Baseline and Measure Packages........................................................................13
3.3.2 Energy Efficiency Measures................................................................................15
3.3.3 HVAC Retrofit .....................................................................................................18 4 Stakeholder Interviews ................................................................................................. 21
4.1 Objectives and Research Questions .........................................................................21
4.2 Results ......................................................................................................................21
4.3 Interpretation.............................................................................................................22 5 Cost-effectiveness Results .......................................................................................... 25
5.1 Small Office...............................................................................................................26
5.1.1 Individual Efficiency Measure Results................................................................. 26
5.1.2 SZAC Package Results ......................................................................................27
5.1.3 SZHP Package Results ......................................................................................28
5.2 Medium Retail ...........................................................................................................29
5.2.1 Individual Efficiency Measure Results................................................................. 29
5.2.2 SZAC Package Results ......................................................................................30
5.2.3 SZHP Package Results ......................................................................................31 6 Reach Code Options..................................................................................................... 32 7 Conclusions and Next Steps................................................................... .....................36 8 References .................................................................................................................... 38 2025 Nonresidential Alterations Reach Code Study 2
2025/07/07
9 Appendices ...................................................................................................................39
9.1 Map of California Climate Zones ...............................................................................39
9.2 Mixed-Fuel Baseline Energy Figures.........................................................................40
9.3 Long-Term Systemwide Cost (LSC) Impacts .............................................................54
9.3.1 Small Office ........................................................................................................54
9.3.2 Medium Retail.....................................................................................................55
9.4 Utility Rate Schedules ...............................................................................................56
9.4.1 Pacific Gas & Electric..........................................................................................57
9.4.2 Southern California Edison .................................................................................59
9.4.3 Southern California Gas......................................................................................62
9.4.4 San Diego Gas & Electric ...................................................................................63
9.4.5 City of Palo Alto Utilities ......................................................................................65
9.4.6 Sacramento Municipal Utilities District (Electric Only) .........................................70
9.4.7 Fuel Escalation Rates.........................................................................................70
9.5 Prototype Characteristics ..........................................................................................72
9.6 Occupancy Schedules and Building Types................................................................75
9.7 Interview Guide .........................................................................................................75 List of Tables
Table 1. Utility Tariffs Used Based on Climate Zone ................................................................ 8 Table 2. Existing Building Prototype Characteristics ............................................................... 11 Table 3. Small Office (SO) Prototype Characteristics, by Vintage...........................................12 Table 4. Medium Retail (RE) Prototype Characteristics, by Vintage .......................................13 Table 5. Summary of Measure Packages ...............................................................................15 Table 6. Lighting Retrofit Lighting Power Density Efficiency Measure Specifications ..............17 Table 7. Applicability and Cost of Energy Efficiency Measures ...............................................17 Table 8. Cost of Energy Efficiency Measures .........................................................................18 Table 9. Small Office Retrofit Costs (Example: Climate Zone 14) ...........................................20 Table 10. Medium Retail HVAC Retrofit Costs (Example: Climate Zone 12)...........................20 Table 11. Cost-Effectiveness for Individual Efficiency Measures: Small Office........................26 Table 12. Cost-Effectiveness for SZAC Packages: Small Office .............................................27 Table 13. Cost-Effectiveness for SZHP Package: Small Office...............................................28 Table 14. Cost-Effectiveness for Individual Efficiency Measures: Medium Retail ....................29 Table 15. Cost-Effectiveness for SZAC Packages: Medium Retail .........................................30 Table 16. Cost-Effectiveness for SZHP Packages: Medium Retail .........................................31 2025 Nonresidential Alterations Reach Code Study 3
2025/07/07
Table 17. HVAC RTU Replacement Reach Code Option 1 Applicability ................................. 33 Table 18. HVAC RTU Replacement Reach Code Option 2 Applicability ................................. 34 Table 19. HVAC RTU Replacement Reach Code Option 3 Applicability (Retail only)..............35 Table 20. Medium Retail: Existing Mixed-Fuel Baseline 1980.................................................40 Table 21. Medium Retail: Existing Mixed-Fuel Baseline 1990.................................................41 Table 22. Medium Retail: Existing Mixed-Fuel Baseline 2000.................................................42 Table 23. Medium Retail: Existing Mixed-Fuel FDD Baseline 1980 ........................................43 Table 24. Medium Retail: Existing Mixed-Fuel FDD Baseline 1990 ........................................44 Table 25. Medium Retail: Existing Mixed-Fuel FDD Baseline 2000 ........................................45 Table 26. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 1980...........................46 Table 27. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 1990...........................47 Table 28. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 2000...........................48 Table 29. Small Office: Existing Mixed-Fuel Baseline 1980 ....................................................49 Table 30. Small Office: Existing Mixed-Fuel Baseline 1990 ....................................................50 Table 31. Small Office: Existing Mixed-Fuel Baseline 2000 ....................................................51 Table 32. Small Office: Mixed-Fuel SZAC Code Minimum Baseline 1990 ..............................53 Table 33. Real Utility Rate Escalation Rate Assumptions .......................................................71 Table 34. Non-res Roof U-Value by CZ for three vintages ......................................................72 Table 35 Non-res Exterior Wall U-Value by CZ for three vintages...........................................73 Table 36. Non-res Window U-Value, SHGC and VT for all vintages .......................................74 Table 37. Equipment Turnover Assumptions ..........................................................................74 List of Figures
Figure 1. Packaged RTU Images ............................................................................................ 4 Figure 2. Seasonal PG&E Historical Gas Rates ................................................................. ..... 8 Figure 3. Equipment Costs by Fuel Type and Unit Capacity...................................................19 Figure 4. Peak Heating Demand as a Percent of Peak Cooling Demand, and Unmet Heating Load Hours ............................................................................................................................23 Figure 5. Heating Capacity as a Percent of Peak Heating Demand from CBECC ..................24 Figure 6. Map of California climate zones. .............................................................................39 Figure 7. Small Office LSC Impacts: MF-EFF vs HP ..............................................................55 Figure 8. Medium Retail LSC Impacts: MF-HRVDCV vs HP ..................................................55 Figure 9. Medium Retail LSC Impacts: MF-EFF vs HP-DCV ..................................................56 Figure 10. Occupancies in 141.0-E-1 Schedules....................................................................75
2025 Nonresidential Alterations Reach Code Study 4
2025/07/07
Executive Summary
The California Codes and Standards (C&S) Reach Codes program provides technical support to local governments considering adopting a local ordinance (reach code) intended to support meeting local and/or statewide energy efficiency and greenhouse gas emissions reduction goals. The program facilitates adoption and implementation of the code when requested by local jurisdictions by providing resources such as cost-effectiveness studies, model language, sample findings, and other supporting documentation.
The Reach Code Team evaluated the energy savings and cost-effectiveness of various measures in three different vintages (1980s, 1990s, and 2000s) of the Small Office and Medium Retail prototypes for this report. The Team analyzed measures include packaged rooftop unit (RTU) replacements as well as efficiency measures, including cool roof, window film, lighting retrofit, HRV, DCV, and economizer FDD.
For packaged rooftop units, the Team found that Single Zone Heat Pump (SZHP) replacements of Single Zone Air Conditioners (SZAC) achieve energy savings and are generally cost-effective. For SZHP up to 20 tons, depending on the climate zone, some additional efficiency measures may be required to achieve cost-effectiveness, while SZHP up to 10 tons are cost-effective without additional efficiency measures. The energy savings and cost-effectiveness of individual energy efficiency measures applied to an existing building without an RTU retrofit or bundled with RTU replacements (both SZACs and SZHPs), vary by prototype, climate zone, and vintage.
Figure 1. Packaged RTU Images
Local jurisdictions may adopt ordinances that amend different Parts of the California Building Standards Code or may elect to amend other state or municipal codes. The decision regarding which code to amend will determine the specific requirements that must be followed for an ordinance to be legally enforceable. Although a cost-effectiveness study is only required to amend Part 6 of the California Building Code, it is important to understand the economic impacts of any policy decision. This study documents the estimated costs, benefits, energy impacts and greenhouse gas emission reductions that may result from implementing an ordinance based on the results to help residents, local leadership, and other stakeholders make informed policy decisions.
Model ordinance language and other resources are posted on the C&S Reach Codes Program website at LocalEnergyCodes.com. Local jurisdictions that are considering adopting an ordinance may contact the program for further technical support at [email protected].
2025 Nonresidential Alterations Reach Code Study 5
2025/07/07
1 Introduction
This report documents cost-effective combinations of measures that exceed the minimum requirements of the 2025 Building Energy Efficiency Standards, effective January 1, 2026, for existing nonresidential buildings. This report was developed in coordination with the California Statewide Investor-Owned Utilities (CA IOUs) Codes and Standards Reach Codes Program, key consultants, and engaged cities—collectively known as the Reach Code Team.
The purpose of this study is to evaluate the cost-effectiveness of measure packages to increase energy performance in existing nonresidential buildings. The Reach Code Team analyzed packages with different combinations of SZHP space heating equipment replacements, HVAC-related efficiency measures, envelope, and lighting efficiency measures.
Analysis used the CBECC (California Building Energy Code Compliance) 2025 software. The Reach Code Team conducted stakeholder interviews and collected cost data for each measure analyzed to determine the cost-effectiveness and technical feasibility of the proposed measures.
The California Building Energy Efficiency Standards Title 24, Part 6 (Energye rgy Code) (CEC, 2025) is maintained and updated every three years by two state agencies: the California Energy Commission (the Energy Commission) and the Building Standards Commission (BSC). In addition to enforcing the code, local jurisdictions have the authority to adopt local energy ordinances—or reach codes—that exceed the minimum standards defined by Title 24 (as established by Public Resources Code Section 25402.1(h)2 and Section 10-106 of the Building Energy Efficiency Standards). Local jurisdictions must demonstrate that the requirements of the proposed ordinance are cost-effective and do not result in buildings consuming more energy than is permitted by Title 24, Part 6. In addition, the jurisdiction must obtain approval from the Energy Commission and file the ordinance with the BSC for the ordinance to be legally enforceable.
The Department of Energy (DOE) sets minimum efficiency standards for equipment and appliances that are federally regulated under the National Appliance Energy Conservation Act, including heating, cooling, and water heating equipment [1]. Since state and local governments are prohibited from adopting higher minimum efficiencies than the federal standards require, the focus of this study is to identify and evaluate cost-effective packages that do not include high efficiency heating, cooling, and water heating equipment or appliances. High efficiency appliances are often the easiest and most affordable measures to increase energy performance. While federal preemption limits reach code mandatory requirements for covered appliances, in practice, builders may install any package of compliant measures to achieve higher performance.
2025 Nonresidential Alterations Reach Code Study 6
2025/07/07
2 Methodology and Assumptions
The Reach Codes Team used the cost-effectiveness methodology detailed in this section to analyze two prototype designs representing a medium retail building and a small office using, as described in Section 3.
The Reach Code Team performed energy simulations using the most recent software available for 2025 Energy Code compliance analysis, CBECC 2025 Subversion (SVN) Revision 8219. LSC results using 2025 software will provide a forward-looking indication of the feasibility of SZHP replacements and efficiency measure packages.
2.1 Cost-Effectiveness
This section describes the approach to calculating cost-effectiveness including benefits, costs, metrics, and utility rate selection.
2.1.1 Benefits
This analysis used both on-bill and Long-term Systemwide Cost (LSC) of energy-based approaches to evaluate cost-effectiveness. Both the on-bill and LSC approaches require estimating energy savings and quantifying costs (incremental measure costs and energy costs) associated with energy measures. The primary difference between on-bill and LSC is how energy is valued:
• On-Bill: This approach uses a customer-based lifecycle cost method that values energy based on estimated site energy usage and customer on-bill savings. It incorporates electricity and natural gas utility rate schedules over a 30-year period for the prototypes, accounting for a 3% discount rate and energy cost inflation as outlined in Appendix 10.3.2.
• LSC: LSC, formerly Time Dependent Valuation (TDV), was developed by the Energy Commission. LSC savings are calculated using hourly LSC factors for both electricity and natural gas provided by the Energy Commission These LSC hourly factors are projected over the 30-year life of the building and incorporate the hourly cost of marginal generation, transmission and distribution, fuel, capacity, losses, and cap-and- trade-based CO2 emissions.1
2.1.2 Costs
The Reach Code Team assessed the incremental costs and savings of the energy packages over the 30-year lifecycle, which is consistent with the Energy Commission’s approach to evaluating measures when the Energy Code is updated. Incremental costs represent the equipment, installation, replacements, and maintenance costs of the proposed measure relative to the 2025 Energy Code minimum requirements or standard industry practices. 1 See Hourly Factors for Source Energy, Long-term Systemwide Cost, and Greenhouse Gas Emissions at https://www.energy.ca.gov/files/2025-energy-code-hourly-factors 2025 Nonresidential Alterations Reach Code Study 7
2025/07/07
The Reach Code Team obtained measure costs from manufacturer distributors, contractors, literature review, and online sources such as RS Means. Taxes and contractor markups were added as appropriate. Maintenance and replacement costs are included.
2.1.3 Metrics
Cost-effectiveness is presented using net present value (NPV) and benefit-to-cost (B/C) ratio metrics.
• NPV: Equation 1 demonstrates how lifetime NPV is calculated. If the NPV of a measure or package is positive, it is considered cost-effective. A negative value represents a net increase in costs over the 30-year lifetime. • B/C Ratio: This is the ratio of the present value of all benefits to the present value of all costs over 30 years (present value benefits divided by present value costs). A value of one indicates the NPV of the savings over the life of the measure is equivalent to the NPV of the lifetime incremental cost of that measure. A value greater than one represents a positive return on investment. The B/C ratio is calculated according to Equation 2.
Improving the energy performance of a building often requires an initial investment. In most cases, the benefit is represented by annual on-bill utility or LSC savings. The cost is represented by incremental first cost and replacement costs. However, some packages result in initial construction cost savings (negative incremental cost), and either energy cost savings (positive benefits) or increased energy costs (negative benefits). In cases where both construction costs and energy-related savings are negative, the construction cost savings are treated as the benefit while the increased energy costs are the cost. In cases where a measure or package is cost-effective immediately (i.e., upfront construction cost savings and lifetime energy cost savings), B/C ratio cost-effectiveness is represented by “>1”. Because of these situations, NPV savings are also reported, which, in these cases, are positive values.
2.1.4 Utility Rates
In coordination with the CA IOU rate team, and the publicly available information for several Publicly Owned Utilities (POUs), the Reach Code Team determined appropriate utility rates for each Climate Zone and package. The utility tariffs, summarized in Table 1, were determined based on the annual load profile of the prototype and the corresponding package and the most prevalent rate in each territory. A time-of-use (TOU) electric rate was applied to all cases.
For a more details on the rates selected refer to Appendix 9.3.2 - Utility Rate Schedules.
The analysis assumes that utility rates escalate over time for commercial buildings, as described in Appendix 9.4.7. Escalation rates above inflation for electricity beyond 2023 are assumed to be between 0.2% and 0.7%, before dropping to a steady 0.6% escalation per year in 2030. Natural gas is assumed to escalate at a relatively higher rate, peaking at 7.7% in 2024, then escalating more slowly to a rate of approximately 2% in the latter years of the analysis period.
2025 Nonresidential Alterations Reach Code Study 8
2025/07/07
Table 1. Utility Tariffs Used Based on Climate Zone
Climate
Zones Electric / Gas Utility Electricity Natural Gas
IOUs
1-5,11-13,16 Pacific Gas & Electric Company (PG&E) B-1 / B-10 G-NR1 6, 8-10, 14, 15 Southern California Edison (SCE) /
Southern California Gas Company (SCG)
TOU-GS-1 / TOU-
GS-2 / TOU-GS3 GN-10
5 PG&E / SCG B-1 / B-10 GN-10
7, 10, 14 San Diego Gas and Electric Company
(SDG&E) TOU-A / AL-TOU GN-3
POUs
4 City of Palo Alto (CPAU) E-2 G-2
12 Sacramento Municipal Utility District
(SMUD) / PG&E CITS-0 / CITS-1 G-NR1
The Reach Code Team conducted an analysis of the gas rates by month to determine seasonal fluctuations. An example of the historical gas rates for PG&E are shown in Figure 2.
Figure 2. Seasonal PG&E Historical Gas Rates
To develop the seasonal gas rates for each utility, the Reach Code Team used an average seasonal curve based on 5-year historical data. The Team then applied the seasonal trend to the current month’s gas rate to reflect the most recent market conditions. In this study, the Reach Code Team collected gas rates from September 2024 for each utility and applied a factor for each month to normalize the monthly gas rate fluctuations. $0.0
$0.5
$1.0
$1.5
$2.0
$2.5
$3.0
1 2 3 4 5 6 7 8 9 10 11 12
$ / Therm
PG&E Historical Gas Rates
2024 2023 2022 2021 2020 2019
2025 Nonresidential Alterations Reach Code Study 9
2025/07/07
2.2 Greenhouse Gas Emissions
The GHG emissions are calculated using the latest applicable GHG Emissions hourly factors published by the Energy Commission and used by the Energy Commission’s reference code compliance software CBECC, and largely represent California IOUs. GHG emissions associated with community choice aggregators or POUs are not integrated into these multipliers and require a custom analysis, using the energy impacts in this report as a starting point.
2025 Nonresidential Alterations Reach Code Study 10
2025/07/07
3 Prototypes, Measure Packages, and
Costs
This section describes the prototypes and the scope of analysis conducted by the Reach Code Team.
3.1 Prior Reach Code Study Research
In 2021, the Statewide CA IOU Reach Codes Team analyzed the cost-effectiveness of non- residential alterations projects for mixed-fuel plus efficiency, SZHP replacements plus efficiency, and demand flexibility packages (Statewide Reach Codes Team 2021). Using this analysis, the Reach Code Team presented reach code options for jurisdictions to consider adopting based on cost-effectiveness. The Reach Code Team leveraged some information from the previous report to develop the results and conclusions in this report, including prototype and vintage characteristics, potential efficiency measures, package combinations, and cost data.
3.2 Prototype Characteristics
The Reach Code Team used modified versions of the Department of Energy (DOE) building prototypes for Medium Retail and Small Office to evaluate cost-effectiveness of measure packages. Existing retail and office occupancies are two of the occupancies that are prescriptively required to have SZHP rooftop units for new or replacement applications under 65,000 BTU/h according to 2025 Energy Code, Section 141.0(b)2Cii and Table 141.0-E-1.
This study analyzes retail and office prototypes specifically because they represent the largest portions of the existing building stock and represent similar occupancy schedules and load profiles as the other occupancies in Table 141.0-E-1, including grocery, school, financial institution, and library occupancies.
To identify appropriate characteristics, the Team created three vintages of each building prototype to represent historical construction practices by leveraging data and methodologies from previous IOU studies, Senate Bill 350 (SB350) analysis2 , and Commercial Building Energy Consumption Survey (CBECS)3 . These datasets include estimates of retrofits/upgrades to older buildings as well as field data on existing conditions. The three vintages that the Reach Code Team analyzed include:
• 1980s: represents buildings built prior to 1990 (code reference year 1982). • 1990s: represents buildings built during the 1990 era (code reference year 1992). • 2000s: represents buildings built during the 2000 era (code reference year 2006). 2 This references an unpublished analysis developed in support of the Energy Commission’s Senate Bill 350:
https://www.energy.ca.gov/rules-and-regulations/energy-suppliers-reporting/clean-energy-and-pollution- reduction-act-sb-350.
3 https://www.eia.gov/consumption/commercial/.
2025 Nonresidential Alterations Reach Code Study 11
2025/07/07
The analysis presented in this report assumes a certain set of existing conditions within each prototype, and that buildings operate as-intended (i.e., no faulty conditions4). Real building existing conditions are often a variety of old and new components, and equipment performance degrades over time. The analysis assumes some equipment replacement over time based on building system and envelope component, using assumptions from the SB350 analysis.
The Reach Code Team’s prototypes and cost-effectiveness results represent a range of vintages to account for the variety of existing conditions in real buildings in a simplified way.
Jurisdictions should consider how measure-specific findings would apply to the existing conditions in the buildings within their area.
Table 2 through Table 4 summarize the existing building prototype characteristics, with more detail available in Appendix 9.5.
Table 2. Existing Building Prototype Characteristics
Small Office Prototype Medium Retail Prototype
Conditioned floor
area (ft2) 5,502 24,563
Number of stories 1 1
Window-to-floor
area ratio 24% 7%
Number of Conditioned
Thermal Zones 5 4
4 The economizer FDD individual measure analysis only assumes a faulty economizer in the existing building baseline.
2025 Nonresidential Alterations Reach Code Study 12
2025/07/07
Table 3. Small Office (SO) Prototype Characteristics, by Vintage Vintage 1980s 1990s 2000s
HVAC System Type Single Zone Packaged
Rooftop Unit (RTU)
Single Zone Packaged
Rooftop Unit (RTU)
Single Zone Packaged
Rooftop Unit (RTU)
Cooling System Direct Expansion (DX)
EER: 8.2
DX
EER: 8.8
DX
EER: 10.3
Heating System Gas Furnace
AFUE: 67.5%
Gas Furnace
AFUE: 78.1%
Gas Furnace
AFUE: 78.1%
Supply Fan Constant volume (CV)
Fan Efficiency: 47.5%
CV
Fan Efficiency: 50.8%
CV
Fan Efficiency: 55.0%
Economizer Control
No Economizer if
cooling capacity < 134
kBtuh,
Otherwise, Economizer
with Differential Dry Bulb
control
No Economizer if cooling capacity < 75 kBtuh,
Otherwise, Economizer with Differential Dry Bulb
control
Service Hot Water
Heating
Electric Conventional Small Storage
Energy Factor: 0.95
Roof Insulation
(U-Value) Vary by CZ, see Appendix 9.5
Steep-Sloped Roof
Solar Reflectance
CZ01: 0.105
Others: 0.117
CZ01: 0.104
Others: 0.114
CZ01: 0.102
Others: 0.2
Metal-Framed Wall
Insulation (U-Value) Vary by CZ, see Appendix 9.5
Windows Vary by CZ, see Appendix 9.5
LPD (W/ft2) 1.2
2025 Nonresidential Alterations Reach Code Study 13
2025/07/07
Table 4. Medium Retail (RE) Prototype Characteristics, by Vintage Vintage 1980s 1990s 2000s
HVAC System Type Single Zone Packaged
Rooftop Unit (RTU)
Single Zone Packaged
Rooftop Unit (RTU)
Single Zone Packaged
Rooftop Unit (RTU)
Cooling System DX
EER: 8.2
DX
EER: 8.8
DX
EER: 10.3
Heating System Gas Furnace
AFUE: 0.675
Gas Furnace
AFUE: 0.781
Supply Fan Control Method: CV
Fan Efficiency: 47.5%
Control Method: CV
Fan Efficiency: 50.8%
Control Method: CV
Fan Efficiency: 55.0%
Economizer Control
No Economizer if
cooling capacity < 134
kBtuh, Otherwise,
Economizer with
Integrated, Differential
Dry Bulb control
No Economizer if cooling capacity < 75 kBtuh,
Otherwise, Economizer with Integrated, Differential
Dry Bulb control
Service Hot Water
Heating
Electricity Conventional Small Storage
Energy Factor: 0.95
Roof Insulation
(U-Value) Varies by CZ, see Appendix 9.5
Low-Sloped Roof
Solar Reflectance 0.182 0.166 0.552
Metal-Framed Wall
Insulation (U-Value) Varies by CZ, see Appendix 9.5
Windows Varies by CZ, see Appendix 9.5
LPD (W/ft2)
Retail spaces: 1.7
Back Space: 0.6
Front Entry: 1.5
3.3 Measure Definitions and Costs
The Reach Code Team analyzed the efficiency measures and HVAC retrofit measures described in this section as applied to the Medium Retail and Small Office prototypes. The sources of measure definitions and associated costs are related to stakeholder interview findings and interpretation discussed in Section 4.
3.3.1 Baseline and Measure Packages
3.3.1.1 Individual Measures
The Reach Code Team analyzed several scenarios. Individual energy efficiency measures were analyzed compared to the existing building baseline. • Existing Building Baseline: Mixed-fuel existing building including a packaged SZAC RTU with a gas-fired furnace, prescriptively built at the time of initial construction, assuming equipment turnover rates. See Appendix 9.5 for more details. • Existing Building + Individual Efficiency Measures: Mixed-fuel existing building, with the following individual efficiency measures.
2025 Nonresidential Alterations Reach Code Study 14
2025/07/07
o Cool roof (Medium Retail only)
o Window film
o Lighting retrofit
o Economizer fault detection and diagnostics (Medium Retail only) All measures assume that the building system alteration is not already included in the proposed alteration scope, except Cool Roof which assumes a roof replacement is already occurring.
3.3.1.2 RTU Replacement + Measure Packages
The Reach Code Team analyzed several scenarios that include a RTU replacement. The baseline for these packages is defined below:
• MF (Mixed-fuel SZAC Code Min Baseline): Mixed-fuel existing building that is replacing all RTUs in accordance with 2025 Energy Code prescriptive requirements.
For units that are 5-ton and below in Climate Zones 3-13 and 15, RTUs are replaced with a single zone heat pump (SZHP) with efficiency set at federal code minimum and economizer. Units above 5-ton and in other Climate Zones will be replaced with a new code minimum single zone air conditioner (SZAC) packaged RTU including a gas-fired furnace.
The RTU replacement packages examined against the MF baseline package are defined below:
• MF-EFF (Mixed-fuel SZAC Code Min + Bundled Efficiency Measures): Mixed-fuel existing building replacing the packaged RTU with a new code minimum SZAC where prescriptively allowed. The following efficiency measures are applied to the package:
o Demand controlled ventilation (DCV, Medium Retail only) o Window film
o Lighting retrofit
• MF-HRV, MF-DCV, and MF-HRVDCV (Mixed-fuel SZAC Code Min + HVAC Measures): Mixed-fuel existing building replacing the packaged RTU with a new code minimum SZAC where prescriptively allowed. The following HVAC efficiency measures are applied to the package:
o Demand controlled ventilation (DCV, Medium Retail only) o Heat recovery ventilation (HRV)
• HP (SZHP Code Min): Mixed-fuel existing building that is replacing all RTUs with a federal code minimum efficiency SZHP up to 20 tons. Units 5 tons and below in Climate Zones 3-13 and 15 are already SZHPs with economizers in the Mixed-fuel SZAC Code Min Baseline, so this package measures impacts from SZHP replacements in the 6-20 ton range and other Climate Zones. • HP-10 (SZHP Code Min ≤10-Ton): Mixed-fuel existing building that is replacing all RTUs with a federal code minimum SZHP up to 10 tons. Units 5 tons and below in 2025 Nonresidential Alterations Reach Code Study 15
2025/07/07
Climate Zones 3-13 and 15 are already SZHPs in the Mixed-fuel SZAC Code Min Baseline, so this package measures impacts from SZHP replacements in the 6-10 ton range and other Climate Zones. Note that this package is the same as HP for the Small Office prototype, because all units are below 10 tons. • HP-DCV (SZHP Code Min + HVAC Measures): Mixed-fuel existing building that is replacing the packaged RTU with a federal code minimum SZHP for units up to 20 tons. The following HVAC efficiency measures are applied to the package:
o Demand controlled ventilation (DCV, Medium Retail only) o Heat recovery ventilation (HRV)
The packages analyzed over the MF baseline are summarized in Table 5 below.
Table 5. Summary of Measure Packages
Package Name SO RE Baseline
Package
Proposed HVAC
System5
HVAC
Efficiency
Measures
Energy
Efficiency
Measures
Individual Measures
COOLROOF X Existing Existing SZAC - Cool roof
WINDOWFILM X X Existing Existing SZAC - Window
LIGHTING X X Existing Existing SZAC - Lighting
ECONOMIZERFDD X Existing6 Existing SZAC - Economizer
FDD
Mixed-Fuel SZAC Replacement Packages
MF-EFF X X
MF SZHP for units ≤ 5-tons in
Climate Zones 3-13 and
15. SZAC elsewhere.
DCV (RE
only)
Window,
Lighting
MF-HRV X X MF Same as above HRV -
MF-DCV X MF Same as above DCV -
MF-HRVDCV X MF Same as above HRV, DCV -
SZHP Replacement Packages
HP X X MF SZHP (≤ 20 tons) - -
HP-10 X MF SZHP (≤ 10 tons) - -
HP-DCV X MF SZHP (≤ 20 tons) HRV, DCV -
3.3.2 Energy Efficiency Measures
The Reach Code Team identified and investigated efficiency measures applicable in alterations scenarios through stakeholder interviews and literature review. 5 All replacement equipment is assumed to be code minimum. This is 81% AFUE and 14 SEER for SZAC packages, and 8 HSPF for SZHP packages.
6 This measure assumes the baseline to be the existing building with a faulty economizer. The measure would restore the economizer on the existing HVAC equipment and add FDD. 2025 Nonresidential Alterations Reach Code Study 16
2025/07/07
3.3.2.1 Measure Descriptions
3.3.2.1.1 Envelope
Cool roof (low-sloped): This measure specifies solar reflectance exceeding 2025 Energy Code Section 141.0(b)2.B for low-sloped requirements when the renovation scope already includes replacing the roof.
o For Medium Retail (low-sloped roof), Climate Zones 2 and 4 through 16: The minimum aged solar reflectance is increased from 0.63 to 0.70. o Climate Zones 1 and 3: No proposed roof measure.
The cool roof individual measure is compared to the minimum aged solar reflectance requirements.
This measure does not apply to steep-sloped Small Office prototype, as cool roof is already required by the Energy Code.
Window Film: This measure reduces window SHGC of existing windows to 0.39 by adding window film. In addition to reducing heat gain, window films can serve as safety and security measures by stabilizing broken glass. Please see Appendix 9.5 for the existing window SHGC, which varies by building type, Climate Zone, and by vintage.
3.3.2.1.2 Heating, Ventilation, and Air Conditioning
Economizer repair and fault detection and diagnostics (FDD): This measure restores existing economizers to be fully functional and installs standalone economizer FDD on existing air handling units with cooling capacity greater than 134,000 Btu/hr in vintage 1980s and 75,000 Btu/hr in vintage 1990s/2000s. The measure recognizes that existing economizers are often non-functional, with the dampers often either failed closed or partially open (DNV KEMA, 2013). This is a standalone measure that can be installed without RTU replacements.
Demand control ventilation (DCV): This measure uses CO2 sensors to reduce ventilation based on actual occupancy for intermittent- or high-occupancy spaces. The DCV measure applies to retail spaces in the Medium Retail prototype. It doesn’t apply to the Small Office prototype since there are no packaged units serving only conference room zones, and the occupancy profile is otherwise relatively flat, leaving no opportunities for occupancy-based savings. This measure is part of RTU replacements.
Heat Recovery Ventilation (HRV): This measure is a mechanical device intended to remove air from buildings, simultaneously replace it with outdoor air, and in the process transfer heat from the warmer to the colder of the simultaneous airflows. This measure adds a wheel-type HRV to the space conditioning system to reduce the heating and cooling demands of the building. The modeling assumptions include fixed temperature control method, fixed supply temperature of 75°F, and a return fan. This measure is implemented on SZAC RTU replacements only.
2025 Nonresidential Alterations Reach Code Study 17
2025/07/07
3.3.2.1.3 Lighting
Lighting retrofit: This measure is an additional improvement beyond the planned renovation scope, which replaces the existing luminaires. The measure reduces the existing LPD in select areas to the following, representing 2025 code-minimum upgrades:
Table 6. Lighting Retrofit Lighting Power Density Efficiency Measure Specifications Prototype Baseline LPD (W/ft2) LPD (W/ft2)
Small office 1.2 0.60
Medium Retail 1.7 0.95
3.3.2.2 Measure Applicability and Costs
The Reach Code team used the efficiency measures summarized in Table 7 below by Climate Zone and prototype. Measure application varies due to existing building and HVAC system characteristics, as well as the retrofit scenario being analyzed.
Table 7. Applicability and Cost of Energy Efficiency Measures
Measure Name Applicable
Climate Zones
Existing Building +
Individual Measures
MF-HRV or MF-
HRVDCV
MF-EFF
Prototype SO RE SO RE SO RE
Cool roof (low-sloped) CZ 2,4-16 X
Window film 1980s vintage
1990s vintage X X X X
Economizer FDD CZ 2-16 X
DCV All X X
HRV All X X
Lighting retrofit All X X X X
2025 Nonresidential Alterations Reach Code Study 18
2025/07/07
Table 8 summarizes the incremental measure costs, including cost data sources and total cost per prototype. Cost sources from previous years have been adjusted for inflation.
Table 8. Cost of Energy Efficiency Measures
Measure
Name
Primary cost
source(s)
Incremental
Cost
Description
Incremental
First Cost for
Small Office
Prototype*
Incremental
First Cost for
Retail
Prototype*
Useful Life /
Replacement
Year
Cool roof
(low-sloped) Distributor/online $0.04/ft2 of roof
area N/A $1,263 30
Window film RS Means $8.83/ft2 of window
area $7,884 $10,053 30
Lighting
retrofit7 Distributor/online RE: $3.93/ft2
SO: $4.29/ft2 $20,807 $87,735 15
DCV
IL TRM8,
adjusted for
location
$1,764 per unit N/A $8,639
Same as HVAC
equipment
(15 years)
Economizer
FDD Distributors
$1,425 - $4,050 per
unit depending
on capacity
N/A $8,861
Same as HVAC
equipment
(15 years)
HRV Market data $4,773 per unit $23,867 $14,320
Same as HVAC
equipment
(15 years)
*When costs differ by vintage, the Team used the 2000s vintage as an example, except Window Film which uses the 1990s vintage. When costs differ by Climate Zone, CZ 12 is used as an example.
3.3.3 HVAC Retrofit
The Team examined the potential for all-electric heat pump retrofits of packaged single zone (SZ) rooftop HVAC where the system size is less than 240,000 kBtuh (20 tons).9 This threshold aligns with 2025 Energy Code new construction prescriptive requirements in section 140.4(a)2 and is representative of manufacturer HVAC products capable of heat pump heating.
The Team received cost estimates for all HVAC equipment from wholesale distributors and contractors. A mechanical contractor provided labor costs for typical new installations and noted that retrofit labor costs are highly variable due to building-specific considerations such as tight working conditions, prepping surfaces, elevated work, material handling, specialty rigging, and protecting existing finishes. The Team assumed the labor for a retrofit would be 25% more than a non-retrofit installation for both the mixed-fuel SZAC and the SZHP HVAC 7 The lighting costs include upgrading compact lighting, upgrading linear lighting, and adding luminaire level lighting controls.
8 2024 IL-TRM Version 12.0 Volume 1: Commercial and Industrial Measures, accessed at https://icc.illinois.gov/downloads/public/il-trm-12/IL- TRM_Effective_010124_v12.0_Vol_2_C_and_I_09222023_FINAL_clean.pdf. 9 For the purposes of this study, the SZHP retrofit package may have some gas usage depending on the vintage and climate zone. Space heating equipment over 20 tons are outside the scope of the analysis, and units of this size will remain the existing mixed-fuel HVAC equipment. 2025 Nonresidential Alterations Reach Code Study 19
2025/07/07
retrofits because in both cases, the packaged units are drop-in replacements at the system level, with no demolition required. No HVAC distribution changes are required as part of the heat pump retrofit.
The HVAC retrofit package costs are shown by unit capacity in Figure 3. This graph does not include labor costs, which are $4,568 for each unit, regardless of fuel type. Additionally, this graph does not include markups for overhead or Climate Zone specific adjustment factors.
Figure 3. Equipment Costs by Fuel Type and Unit Capacity For these building types, we assume no impact on electrical infrastructure because equipment capacity is driven by the cooling load and not the heating load. Therefore, the equipment capacity (and the electrical infrastructure required) would be the same for the all-electric case as the mixed-fuel/existing building case.
The Team assumed that both SZAC HVAC equipment and SZHP HVAC equipment have a 15- year useful life [2]. We assume that HVAC equipment is replaced at the end of its useful life.
The Team assumed that the maintenance requirements would be the same in the SZAC and SZHP scenarios, and do not have incremental impact.
3.3.3.1 Small Office
The existing HVAC system includes five packaged SZACs. The Reach Code Team selected packaged SZHPs to replace the existing packaged RTUs for the Small Office SZHP retrofit.
Table 9 shows an example of the incremental cost associated with the SZHP package for Small Office over the 30-year lifecycle. In Climate Zones 3-13 and 15, all units are 5 tons or less which are SZHPs in the baseline for the 1990s and/or the 2000s vintage, so the table below uses Climate Zone 14 costs as an example to show the comparison across vintages. -$5,000
$0
$5,000
$10,000
$15,000
$20,000
$25,000
$30,000
$35,000
3 4 5 6 7.5 8.5 10 12.5 15 20
Equipment Cost
Capacity (Tons)
SZAC SZHP Incremental Cost
2025 Nonresidential Alterations Reach Code Study 20
2025/07/07
Table 9. Small Office Retrofit Costs (Example: Climate Zone 14) Vintage SZAC
Measure
SZAC
Cost
SZHP
Retrofit
Measure
SZHP
Retrofit Cost
SZHP
Incremental
First Cost
Equipment
Capacities
1980s
Packaged
SZAC + gas
furnace
$93,733 Packaged
SZHP $87,422 - $6,311
One 4-ton unit,
three 5-ton units,
one 6-ton unit
1990s
Packaged
SZAC + gas
furnace
$85,744 Packaged
SZHP $75,052 - $10,693
One 3-ton unit,
three 4-ton units,
one 5-ton unit
2000s
Packaged
SZAC + gas
furnace
$85,164 Packaged
SZHP $75,229 - $9,936
Two 3-ton units,
two 4-ton units, one
5-ton unit
As shown in Table 9, the incremental costs across vintages do not vary as much for Small Office compared to the Medium Retail prototype because all HVAC units have a capacity of less than 10 tons.
3.3.3.2 Medium Retail
The existing HVAC system includes four packaged SZ rooftop air-conditioners (AC) with gas furnaces which are less than 20 tons. Note that the core zone in the Medium Retail has a unit over 20 tons and is thus excluded from the analysis. The Reach Code Team selected packaged SZHPs to replace the three existing packaged RTUs below 20 tons for the Medium Retail SZHP retrofit. Table 10 shows an example of the incremental first cost associated with the SZHP package for Medium Retail over the 30-year lifecycle.
Table 10. Medium Retail HVAC Retrofit Costs (Example: Climate Zone 12) Vintage SZAC
Measure
SZAC
Cost
SZHP
Retrofit
Measure
SZHP
Cost
SZHP
Incremental
First Cost
Equipment
Capacities
1980s
Packaged
SZAC + gas
furnace
$94,531 Packaged
SZHP $111,596 $17,065 Three 12.5-ton
units
1990s
Packaged
SZAC + gas
furnace
$82,431 Packaged
SZHP $84,368 $1,937 Three 10-ton units
2000s
Packaged
SZAC + gas
furnace
$78,147 Packaged
SZHP $79,204 $1,057 Two 9-ton units,
one 10-ton unit
As shown in Table 10, the incremental cost can vary significantly across the vintages, which is mainly driven by the equipment capacities. In the 2000s vintage example, there is a modest incremental cost, and all HVAC units are 10 tons or less. More recent vintages often have smaller equipment capacities because of the efficiency improvements from code. In the 1980s vintage example, the incremental cost is significant due to the HVAC units all having a capacity of greater than 10 tons.
2025 Nonresidential Alterations Reach Code Study 21
2025/07/07
4 Stakeholder Interviews
To support the code pathway options, the Reach Code Team interviewed five HVAC designers, three HVAC contractors, and two equipment distributors/ manufacturer representatives (“reps”) to gather information regarding their experience with replacing units within this size range, and their opinions of the challenges associated with replacing packaged SZAC + gas furnaces with packaged SZHP.
4.1 Objectives and Research Questions
The team conducted ten interviews focusing on the major factors that influence the replacement of a gas-fired packaged unit with a heat pump including physical constraints, electrical concerns, and capacity issues. The interview questions are provided in Appendix
9.6. 4.2 Results
Overall, eight of ten interviewees related challenges when replacing gas packs with heat pumps. Those challenges included:
• Leaving air temperature of heat pump being lower than a gas pack, • Condensate production on the outdoor coil during heating cycle, • Cool air being delivered to the space during the defrost cycle, particularly in occupancies with large outdoor air changes per hour and in colder climates, • Difficulty handling high outside air loads and associated electrical upgrades, and • Physical constraints, such as structural, footprint, existing duct configuration, and height issues.
The most common physical constraint reported by interviewees (n=6) was the need for an adapter curb during replacement, which has some minimal cost associated with configuration.
Two interviewees noted that this was necessary about 50% of the time regardless of whether the retrofit involved a SZAC or SZHP.
All of the designers and contractors the team interviewed (n=8) noted electrical issues as being concerns during retrofit, but generally uncommon. While power for the cooling for the packaged SZ AC + gas furnace is equal to or larger than the power demand from a heat pump during heating mode, the main electrical concern had to do with the installation of electric resistance for defrost control. Defrost cycles occur when the outdoor coil freezes during heating, and the unit needs to switch to air-conditioning mode for three to five minutes to melt the frost and improve heating efficiency. This concern is minimal as it may only trigger a circuit upgrade and not a building service upgrade. One contractor, however, did state that electrical power is more of a concern in older buildings because of prior improvements to the building, and the potential for the building service to not have the capacity to handle an additional electrical upgrade.
2025 Nonresidential Alterations Reach Code Study 22
2025/07/07
The necessity of electric resistance for defrost control is debatable according to interview responses:
• There was no consensus as to a particular rule of thumb used for specification by designers. One cited an outside air load of more than 30-50%, another cited less than 20°F ambient conditions, and another mentioned specifying electric resistance as a precaution against minor discomfort.
• Similarly, there was no real consensus among contractors as two mentioned humid conditions in cold Climate Zones and another would simply include it as a precaution. • Distributors had consistent answers. Two mentioned that it was installed for back up heat, and another mentioned cold ambient conditions less than 33°F. However, neither distributor interviewed had encountered a situation where a heat pump was not able to maintain the space setpoint because electric resistance hadn’t been installed.
Interviewees commented that heating capacity is an issue during a heat pump retrofit.
However, different interviewee groups cited varying issues:
• Designers had concerns with high outside air capacities and low ambient conditions hindering heat pump heating capacity.
• Contractors mainly cited the defrost cycle as the biggest heating issue with heat pumps since the supply air temperature is cooler during the defrost cycle. • Distributors and manufacturer representatives also mentioned system performance at low outdoor ambient conditions and the defrost cycle as being heating concerns for heat pumps.
Two interviewees cited leaky building envelope issues as a heating concern, but this was unrelated to heat pump retrofits.
4.3 Interpretation
The Reach Code Team considered the issues raised by interviewees and concluded they do not result in significant cost implications, as described below:
• The lower leaving air temperature of heat pumps relative to gas packs increases heating duration but does not necessarily lead to comfort or feasibility issues. • Condensate production during the heating cycle is normal and can be routed in a similar way as the cooling cycle condensation.
• Cool air being delivered to the space during the defrost cycle is likely to happen only during peak heating events when overnight temperatures approach freezing, which is limited in commercial applications that primarily have daytime occupancy and operation.
• Physical constraints, such as structural, footprint, and height issues occur when replacing old equipment with similar size new models and manufacturers and are not associated specifically with heat pump retrofits.
2025 Nonresidential Alterations Reach Code Study 23
2025/07/07
Due to conflicting interviewee feedback on the potential need for electric resistance for supplemental heat as well as defrost cycles, the Team performed additional analysis using CBECC.
Figure 4 depicts the auto-sized single-zone heat pump (SZHP) peak heating demand as a percentage of the peak cooling demand, along with the unmet heating load hours (UMLH) for units without electric resistance backup. In all Climate Zones, peak cooling demand is larger than peak heating demand and thus drives compressor sizing. Furthermore, for electrical supplemental heat, there are very limited UMLH, barely breach 200 hours in CZ16. This data suggests that backup electrical heat is not necessary in all California Climate Zones, except perhaps CZ16.
In Figure 5 the need for electric resistance heating for the purpose of defrost is tested by measuring the heating capacity of the heat pump unit, compared to the actual peak heating demand. Because the default heating capacity of the rooftop units is at least 120% of the peak heating demand for the building in all Climate Zones, the Team estimates that heat pumps will be able to defrost relatively quickly and without causing sustained discomfort.
Based on these two assessments, the need for electrical upgrades associated with heat pump retrofits appears to be minimal, and thus does not require inclusion in cost-effectiveness analysis.
Figure 4. Peak Heating Demand as a Percent of Peak Cooling Demand, and Unmet Heating Load Hours
-
50 100
150
200
250
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
cz01 cz02 cz03 cz04 cz05 cz06 cz07 cz08 cz09 cz10 cz11 cz12 cz13 cz14 cz15 cz16 Unmet Heating Load Hours
H/C Ratio
Climate Zone
Medium Retail Small Office Medium Retail Unmet Heating Load hours 2025 Nonresidential Alterations Reach Code Study 24
2025/07/07
Figure 5. Heating Capacity as a Percent of Peak Heating Demand from CBECC 0%
20%
40%
60%
80%
100%
120%
140%
160%
180%
200%
cz01 cz02 cz03 cz04 cz05 cz06 cz07 cz08 cz09 cz10 cz11 cz12 cz13 cz14 cz15 cz16 Peak Heating Capacity/Peak Heating
Demand
Climate Zone
Medium Retail
Small Office
2025 Nonresidential Alterations Reach Code Study 25
2025/07/07
5 Cost-effectiveness Results
Results are presented as per the prototype-specific Measure Packages described in Section
3. The LSC and On-Bill based, cost-effectiveness results are presented in terms of B/C ratio and NPV section. What constitutes a benefit or a cost varies with the scenarios because both energy savings and incremental construction costs may be negative depending on the package. Typically, utility bill savings are categorized as benefits, while incremental construction costs are treated as costs. In cases where both construction costs are negative and utility bill savings are negative, the construction cost savings are treated as the benefit, while the utility bill negative savings are as the cost. In Table 11 through Table 13, the results Both (shown in green shading) indicates that the result is cost-effective in both On-Bill and LSC. The result On-Bill or LSC (shown in yellow shading) indicates that the result is either cost-effective in On-Bill or LSC, respectively. The result [-] (results with no shading) indicates that the result is not cost-effective On-Bill or LSC. Results that are blank (shown in gray shading) indicate that the package or measure is not applicable, for example, if there are not relevant tonnage of equipment in a vintage.
There are several overarching factors to keep in mind when reviewing the results including:
• SZHP packages will have lower GHG emissions than SZAC packages in all cases, due to the clean power sources currently available from California’s power providers. • To pass the Energy Commission’s application process, local reach codes must have at least one pathway that is cost-effective and exceeds the energy performance budget using LSC (i.e., have a positive compliance margin). Other pathways must also exceed the energy performance budget but are not required to be cost-effective. To emphasize these two important factors, the modeling results that have demonstrated both LSC savings or are cost effective are highlighted in green in the figures within this section.
• As mentioned in Section 2.1.4, The Reach Code Team coordinated with utilities to select tariffs for each prototype given the annual energy demand profile and the most prevalent rates in each utility territory. The Reach Code Team did not compare a variety of tariffs to determine their impact on cost-effectiveness. Utility rate updates can affect cost-effectiveness results.
• As a point of comparison, mixed-fuel SZAC baseline energy figures are provided in Appendix 9.2.
For each prototype, the Reach Code Team assessed the viability of achieving a cost-effective outcome when combining efficiency measures with heat pump packages (e.g., the Heat Pump HVAC + Bundled Efficiency Measures packages) based on the NPVs achieved from each individual efficiency measure.
2025 Nonresidential Alterations Reach Code Study 26
2025/07/07
5.1 Small Office
5.1.1 Individual Efficiency Measure Results
Table 11 shows cost-effectiveness results of individual efficiency measures applied to the existing mixed-fuel Small Office prototype. Window Film and Lighting Retrofit are mostly On-Bill cost-effective in most Climate Zones across the vintages.
Table 11. Cost-Effectiveness for Individual Efficiency Measures: Small Office
Climate
Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E Window
Film 1980s ─ On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill Both Both Both Both Both Both On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ Both ─
Window
Film 1990s ─ On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill Both Both Both Both Both Both On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ Both ─
Window
Film 2000s
Lighting
Retrofit
1980s
On-
Bill
On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill ─ On-Bill ─ ─ On-Bill ─ On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ LSC On-
Bill
Lighting
Retrofit
1990s
On-
Bill
On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill ─ On-Bill ─ ─ On-Bill ─ On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ ─ On-
Bill
Lighting
Retrofit
2000s
On-
Bill
On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill ─ On-Bill ─ ─ On-Bill ─ On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ ─ On-
Bill
2025 Nonresidential Alterations Reach Code Study 27
2025/07/07
5.1.2 SZAC Package Results
Table 12 shows the cost-effectiveness results of the Small Office for SZAC packages. The MF-EFF package is mostly either On-Bill or LSC cost- effective in all applicable Climate Zones across the three vintages. Due to package optimization, there are some Climate Zones excluded because no cost-effective measures are applicable. The MF-HRV package is not presented in this table because it is not cost-effective in any Climate Zones across the three vintages. However, the results are included in the Results Workbook for reference.
Table 12. Cost-Effectiveness for SZAC Packages: Small Office Climate
Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E MF-EFF
1980s LSC LSC On-
Bill
On-
Bill
On-
Bill
On-
Bill ─ On-Bill LSC On-
Bill On-Bill ─ On-
Bill
On-
Bill
On-
Bill LSC ─ LSC
MF-EFF
1990s LSC LSC On-
Bill
On-
Bill
On-
Bill
On-
Bill
On-
Bill On-Bill LSC On-
Bill On-Bill ─ On-
Bill
On-
Bill
On-
Bill LSC ─ LSC
MF-EFF
2000s LSC LSC On-
Bill
On-
Bill
On-
Bill
On-
Bill On-Bill On-Bill On-
Bill
On-
Bill
On-
Bill LSC LSC
2025 Nonresidential Alterations Reach Code Study 28
2025/07/07
5.1.3 SZHP Package Results
Table 13 shows the cost-effectiveness results of the Small Office for SZHP packages. The HP package is cost-effective in both metrics across most Climate Zones and vintages. In vintage 1990s and 2000s, only select Climate Zones are applicable, as most units are 5 tons or below and are prescriptively required to be SZHPs under the 2025 code.
Table 13. Cost-Effectiveness for SZHP Package: Small Office Climate
Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E HP
1980s Both Both Both Both Both Both On-
Bill Both Both Both Both Both Both Both Both Both Both Both Both Both Both HP
1990s Both Both On-
Bill
On-
Bill On-Bill On-
Bill Both Both
HP
2000s Both Both Both Both Both
2025 Nonresidential Alterations Reach Code Study 29
2025/07/07
5.2 Medium Retail
5.2.1 Individual Efficiency Measure Results
Table 14 shows cost-effectiveness results of individual efficiency measures applied to the existing mixed-fuel Medium Retail prototype. The Cool Roof, Lighting Retrofit, and Economizer FDD measures as individual measures are On-Bill and LSC cost-effective in most Climate Zones and vintages where they are applicable. Window Film is mostly On-Bill and LSC cost-effective in selected Climate Zones and vintages.
Table 14. Cost-Effectiveness for Individual Efficiency Measures: Medium Retail Climate Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E Cool Roof 1980s On-
Bill
On-
Bill
On-
Bill Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both ─ Cool Roof 1990s On-
Bill
On-
Bill
On-
Bill Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both ─ Cool Roof 2000s On-
Bill
On-
Bill
On-
Bill Both Both Both Both Both Both Both Both On-
Bill
On-
Bill On-Bill Both Both Both Both ─
Window Film
1980s ─ On-
Bill
On-
Bill
On-
Bill ─ On-
Bill
On-
Bill Both Both Both Both Both Both On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ Both ─
Window Film
1990s ─ On-
Bill ─ On-
Bill ─ On-
Bill
On-
Bill Both Both Both Both Both Both On-
Bill
On-
Bill ─ On-
Bill On-Bill ─ Both ─
Window Film
2000s
Lighting Retrofit
1980s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Lighting Retrofit
1990s LSC Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Lighting Retrofit
2000s LSC Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Economizer FDD
1980s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Economizer FDD
1990s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Economizer FDD
2000s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both
2025 Nonresidential Alterations Reach Code Study 30
2025/07/07
5.2.2 SZAC Package Results
Table 15 shows the cost-effectiveness results of the SZAC Medium Retail measure packages. The MF-EFF package is cost-effective in terms of LSC and On-Bill in most Climate Zones and vintages. The MF-HRVDCV package is partially cost-effective in terms of On-Bill due to the smaller savings compared to the incremental package cost.
Table 15. Cost-Effectiveness for SZAC Packages: Medium Retail Climate
Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E MF-EFF
1980s LSC Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both MF-EFF
1990s LSC Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both MF-EFF
2000s LSC Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both MF-
HRVDCV
1980s
Both Both On-
Bill Both Both Both Both ─ On-Bill On-
Bill
On-
Bill On-Bill On-
Bill Both Both Both Both Both Both Both Both
MF-
HRVDCV
1990s
Both Both ─ Both Both Both Both ─ ─ On-
Bill
On-
Bill On-Bill On-
Bill Both Both Both Both Both Both On-
Bill Both
MF-
HRVDCV
1990s
Both Both ─ Both Both Both Both ─ ─ On-
Bill
On-
Bill On-Bill On-
Bill Both Both Both Both Both Both On-
Bill Both
MF-
HRVDCV
2000s
Both Both Both Both Both Both Both ─ ─ On-
Bill
On-
Bill Both Both Both Both Both Both Both Both On-
Bill LSC
2025 Nonresidential Alterations Reach Code Study 31
2025/07/07
5.2.3 SZHP Package Results
Table 16 shows the cost-effectiveness results of the SZHP packages for Medium Retail. The HP package is mostly cost-effective in terms of On-Bill in some Climate Zones in the 1980s and 1990s vintages. The Climate Zones where the package is not cost-effective is partly due to the large incremental first cost of switching to a SZHP HVAC system for larger capacity units over 10 tons. SZHP retrofits become cost effective in most Climate Zones in the 2000s vintage because of the lower incremental costs associated with smaller system sizes. Comparing this with the HP-10 package where only units at 10-ton or below are replaced with SZHPs, we can see improvements in the cost-effectiveness in terms of LSC and On-bill in applicable Climate Zones.
Table 16. Cost-Effectiveness for SZHP Packages: Medium Retail Climate
Zone CZ1 CZ2 CZ3 CZ4 CZ4 CZ5 CZ5 CZ6 CZ7 CZ8 CZ9 CZ10 CZ10 CZ11 CZ12 CZ12 CZ13 CZ14 CZ14 CZ15 CZ16 Utility PG&E PG&E PG&E PG&E CPAU PG&E SCG SCE SDG&E SCE SCE SDG&E SCE PG&E PG&E SMUD PG&E SDG&E SCE SCE PG&E HP 1980s Both On-
Bill Both On-
Bill
On-
Bill Both LSC On-
Bill ─ ─ ─ ─ ─ On-
Bill
On-
Bill
On-
Bill
On-
Bill ─ On-
Bill ─ On-
Bill
HP 1990s Both On-
Bill Both On-
Bill
On-
Bill
On-
Bill ─ ─ ─ ─ On-
Bill ─ ─ Both Both Both Both LSC Both ─ On-
Bill
HP 2000s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both ─ On- Bill
HP-10
1980s Both Both Both Both Both Both
HP-10
1990s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both On-Bill On- Bill Both
HP-10
2000s Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both Both On- Bill
On-
Bill
HP-DCV
1980s Both Both Both Both Both Both LSC On-
Bill ─ ─ On-
Bill On-Bill On-
Bill Both Both Both Both LSC Both On-
Bill
On-
Bill
HP-DCV
1990s Both On-
Bill Both Both Both On-
Bill ─ ─ ─ On-
Bill
On-
Bill On-Bill On-
Bill Both Both Both Both LSC Both ─ On-
Bill
HP-DCV
2000s Both Both Both Both Both Both Both Both Both Both Both Both ─ Both Both ─ Both Both ─ ─ On- Bill
2025 Nonresidential Alterations Reach Code Study 32
2025/07/07
6 Reach Code Options
Adopting a reach code based on this package of measures is feasible in Climate Zones where:
1. There is an LSC compliant package. This report prioritizes SZHP LSC compliance; and
2. SZHP and SZAC packages have equivalent LSC savings, allowing for both a SZHP and SZAC pathway; and
3. At least one of the SZHP or SZAC is either LSC or on-bill cost-effective.
If one package is cost -effective and the other package achieves LSC equivalency with the cost - effective package, then this reach code pathway could be considered within that Climate Zone.
HVAC RTU Replacement Reach Code Options include:
• Option 1: HP OR MF-HRV OR MF-HRVDCV: This reach code would require a SZHP up to 20 tons, or SZAC with additional HVAC efficiency measures. • Option 2: HP-10 OR MF-HRV OR MF-HRVDCV: This reach code would require SZHP replacements for units up to 10 tons or require additional HVAC efficiency measures for SZAC replacements.
• Option 3: HP-DCV OR MF-EFF: This reach code option increases the number of efficiency measures required as part of the RTU replacement and higher upfront costs and thus could be considered where Options 1 or 2 cannot be adopted. This reach code requires additional efficiency measures, including HVAC, as well as envelope and lighting if SZAC systems are installed.
The RTU replacement reach code options are evaluated in each Climate Zone and vintage and categorized based on the cost-effectiveness and LSC savings of the two pathways. For each reach code option, the primary pathway should be cost-effective under the assumption that the RTU will be replaced as part of the proposed project scope, and the alternative pathway should achieve at least as much LSC savings. The team evaluated several tiers of this reach code option with different requirements for the primary pathway. The primary pathway is a SZHP replacement for Option 1, SZHP replacements for units up to 10 tons only for Option 2, and SZHP replacements with additional HVAC measures for Option 3. If Option 1 is cost-effective, it will cover the broadest set of equipment with the simplest requirements for the SZHP. If Option 1 is not cost-effective, Options 2 or 3 may be considered.
The tables presented in this section show the results for each reach code option and Climate Zone. The primary pathway shows the number of prototypes that are cost-effective, and the number of prototypes analyzed. The alternative pathway shows the number of prototypes that meet or exceed the LSC savings of the primary pathway, regardless of whether they are cost-effective, and the number of prototypes that were analyzed. Note that due to differences in the prototypes, RTU capacities, and measure applicability, not all packages were able to be modeled for all Climate Zones, vintages, and building types. 2025 Nonresidential Alterations Reach Code Study 33
2025/07/07
Table 17 shows the results for the RTU Replacement Reach Code Option 1, where the SZHP replacement is the primary pathway. The alternative pathways analyzed for energy equivalency are the SZAC replacement with HRV only, which is not consistently cost- effective in all cases, and the SZAC replacement with HRV and DCV measures. The DCV measure was not modeled in the small office prototype because there are no packaged units serving only conference room zones and the occupancy profile is otherwise relatively flat. Because DCV was modeled in only one prototype, there are three modeled scenarios for this pathway (the Retail vintages) rather than six scenarios for the other pathways (both Small Office and Retail). However, because offices will have conference rooms and thus can achieve occupancy-based savings for DCV, the results are presented below and treated as widely applicable. Results show that the primary SZHP pathway is cost-effective for more than half of all Climate Zones and vintages.
Table 17. HVAC RTU Replacement Reach Code Option 1 Applicability Primary Pathway – Count
of prototypes that are C/E
Alternative Pathway - Count of
prototypes that achieve LSC equivalency
Climate Zone Utility HP MF-HRV MF-HRVDCV
CZ1 PG&E 6 / 6 3 / 6 3 / 3
CZ2 PG&E 6 / 6 5 / 6 3 / 3
CZ3 PG&E 4 / 4 4 / 4 3 / 3
CZ4 PG&E 4 / 4 4 / 4 3 / 3
CZ4-2 CPAU 4 / 4 4 / 4 3 / 3
CZ5 PG&E 4 / 4 4 / 4 3 / 3
CZ5-2 SCG 3 / 4 4 / 4 3 / 3
CZ6 SCE 3 / 4 3 / 4 3 / 3
CZ7 SDG&E 2 / 4 2 / 4 3 / 3
CZ8 SCE 3 / 5 3 / 5 3 / 3
CZ9 SCE 4 / 5 3 / 5 3 / 3
CZ10 SDG&E 3 / 5 3 / 5 3 / 3
CZ10-2 SCE 3 / 5 3 / 5 3 / 3
CZ11 PG&E 4 / 4 4 / 4 3 / 3
CZ12 PG&E 4 / 4 4 / 4 3 / 3
CZ12-2 SMUD 4 / 4 4 / 4 3 / 3
CZ13 PG&E 4 / 4 4 / 4 3 / 3
CZ14 SDG&E 5 / 6 6 / 6 3 / 3
CZ14-2 SCE 3 / 6 6 / 6 3 / 3
CZ15 SCE 1 / 4 4 / 4 3 / 3
CZ16 PG&E 6 / 6 6 / 6 3 / 3
2025 Nonresidential Alterations Reach Code Study 34
2025/07/07
The Reach Code Team evaluated the cost-effectiveness as it relates to the average capacity of each variation and determined that the SZHP alone is generally cost-effective when the average capacity is around 10 tons or less. The Reach Code Team re-ran the above packages implementing a limit of 10 tons. For the RTU Replacement Reach Code Option 2 results presented in Table 18, the primary pathway is a SZHP replacement for units 5-10 tons, and units 10-20 tons remain the same as the baseline. The same measures are considered for the alternative SZAC pathway as RTU Replacement Reach Code Option 1.
Table 18. HVAC RTU Replacement Reach Code Option 2 Applicability Primary Pathway –
Count of
prototypes that are
C/E
Alternative Pathway - Count of
prototypes that achieve LSC
equivalency
Climate Zone Utility HP-10 MF-HRV MF-HRVDCV
CZ1 PG&E 6 / 6 3 / 6 3 / 3
CZ2 PG&E 5 / 5 4 / 5 2 / 2
CZ3 PG&E 4 / 4 4 / 4 3 / 3
CZ4 PG&E 3 / 3 3 / 3 2 / 2
CZ4-2 CPAU 3 / 3 3 / 3 2 / 2
CZ5 PG&E 4 / 4 4 / 4 3 / 3
CZ5-2 SCG 4 / 4 4 / 4 3 / 3
CZ6 SCE 4 / 4 3 / 4 3 / 3
CZ7 SDG&E 4 / 4 3 / 4 3 / 3
CZ8 SCE 4 / 4 2 / 4 2 / 2
CZ9 SCE 4 / 4 2 / 4 2 / 2
CZ10 SDG&E 4 / 4 2 / 4 2 / 2
CZ10-2 SCE 4 / 4 2 / 4 2 / 2
CZ11 PG&E 3 / 3 3 / 3 2 / 2
CZ12 PG&E 3 / 3 3 / 3 2 / 2
CZ12-2 SMUD 3 / 3 3 / 3 2 / 2
CZ13 PG&E 3 / 3 3 / 3 2 / 2
CZ14 SDG&E 5 / 5 5 / 5 2 / 2
CZ14-2 SCE 2 / 5 5 / 5 2 / 2
CZ15 SCE 2 / 2 2 / 2 1 / 1
CZ16 PG&E 5 / 5 5 / 5 2 / 2
RTU Replacement Reach Code Option 3 results, summarized in Table 19, show the SZHP replacement with DCV as the primary pathway and the mixed-fuel SZAC replacement with DCV, lighting retrofit, and window film as the alternative pathway. The HRV measure is 2025 Nonresidential Alterations Reach Code Study 35
2025/07/07
excluded from the primary pathway because it is not cost-effective across all Climate Zones.
For Climate Zones and vintages that are cost-effective and energy equivalent for multiple reach code options, Option 1 is the more stringent option. Because there is an Option 1 RTU Replacement Reach Code available for all Climate Zones and vintages for Small Office, Option 3 was only evaluated for the Retail prototype.
Table 19. HVAC RTU Replacement Reach Code Option 3 Applicability (Retail only) Primary Pathway – Count
of prototypes that are
C/E
Alternative Pathway -
Count of prototypes that
achieve LSC equivalency
Climate Zone Utility HP-DCV MF-EFF
CZ1 PG&E 3 / 3 3 / 3
CZ2 PG&E 3 / 3 3 / 3
CZ3 PG&E 3 / 3 3 / 3
CZ4 PG&E 3 / 3 3 / 3
CZ4-2 CPAU 3 / 3 3 / 3
CZ5 PG&E 3 / 3 3 / 3
CZ5-2 SCG 2 / 3 3 / 3
CZ6 SCE 2 / 3 3 / 3
CZ7 SDG&E 1 / 3 3 / 3
CZ8 SCE 2 / 3 3 / 3
CZ9 SCE 3 / 3 3 / 3
CZ10 SDG&E 3 / 3 3 / 3
CZ10-2 SCE 3 / 3 3 / 3
CZ11 PG&E 3 / 3 3 / 3
CZ12 PG&E 3 / 3 3 / 3
CZ12-2 SMUD 3 / 3 3 / 3
CZ13 PG&E 3 / 3 3 / 3
CZ14 SDG&E 2 / 3 3 / 3
CZ14-2 SCE 3 / 3 3 / 3
CZ15 SCE 1 / 3 3 / 3
CZ16 PG&E 3 / 3 3 / 3
2025 Nonresidential Alterations Reach Code Study 36
2025/07/07
7 Conclusions and Next Steps
The Reach Codes Team developed packages with SZHPs and energy efficiency measures, simulated them in building modeling software, and gathered costs to determine the cost- effectiveness of multiple scenarios. The Reach Codes Team coordinated with multiple utilities, cities, and building community experts to develop a set of assumptions considered reasonable in the current market. Changing assumptions—such as the period of analysis, measure selection, cost assumptions, energy escalation rates, or utility tariffs—are likely to change results.
Jurisdictions statewide can adopt a variety of building reach codes using the results in this report. While results are nuanced by vintage, Climate Zone, and utility, the overarching takeaways by prototype using the assumptions in this report are summarized below:
• Small Office: Code minimum packaged SZHP space conditioning replacements are cost-effective in all Climate Zones and vintages. The bundled efficiency measure package is cost-effective for both SZAC (like-for-like) and SZHP replacements. The HRV measure is not cost-effective with the SZHP replacement. There are some individual efficiency measures that are cost-effective, depending on Climate Zone and vintage, including window film and lighting retrofit. • Medium Retail: Code minimum packaged SZHP space conditioning replacements are mainly cost-effective in the 2000s vintage, and where HVAC replacements are ≤ 10 tons. In the 1980s and 1990s vintages, which require larger equipment (>10 tons), SZHPs show more variation in cost-effectiveness based on the larger incremental cost of SZHP equipment. With the bundled efficiency measures, code minimum SZAC space heating replacements are cost-effective in all Climate Zones.
There are several cost-effective individual efficiency measures, depending on Climate Zone and vintage, including cool roof, economizer FDD, window film, and lighting retrofit.
Based on these results, the Reach Code Team has identified the following potential measure packages that jurisdictions in most Climate Zones and utility territories may consider adopting based on cost-effectiveness during RTU replacements. The RTU Replacement Reach Code options are as follows:
• Option 1: SZHP Code Min (up to 20 tons) or Mixed-fuel SZAC Code Min + HVAC Measures
• Option 2: SZHP Code Min (up to 10 tons) or Mixed-fuel SZAC Code Min + HVAC Measures
• Option 3: SZHP Code Min + HVAC Measures or Mixed-fuel SZAC Code Min + Bundled Efficiency Measures
Generally, the Reach Code Team found that at least one RTU Replacement Reach Code option may be considered for adoption for all Climate Zones, although in several Climate Zones the option may not be cost-effective across all vintages and prototypes modeled. The 2025 Nonresidential Alterations Reach Code Study 37
2025/07/07
Reach Code options may be applied to a wider set of prototypes, including libraries, grocery, banks, and schools, as described in Section 3.2.
This analysis was limited to the measure packages and building types described. There may be other energy efficiency measures that are cost effective in some or all climate zones, and other building prototypes relevant to what is being retrofit in a particular region of California.
To request custom analysis, please contact [email protected]. 2025 Nonresidential Alterations Reach Code Study 38
2025/07/07
8 References
[1] E-CFR, "https://www.ecfr.gov/cgi-
bin/retrieveECFR?gp=&SID=8de751f141aaa1c1c9833b36156faf67&mc=true&n=pt10.3.43 1 &r=PART&ty=HTML#se10.3.431_197," 2020. [Online]. Available: https://www.ecfr.gov/cgi- bin/retrieveECFR?gp=&SID=8de751f141aaa1c1c9833b36156faf67&mc=true&n=pt10.3.43 1 &r=PART&ty=HTML#se10.3.431_197.
[2] California Energy Commission, 2024. [Online]. Available:
https://efiling.energy.ca.gov/GetDocument.aspx?tn=256847&DocumentContentId=92661. [3] Statewide Reach Code Team, "2019 Cost-effectiveness Study: Low-Rise Residential New Construction. Prepared for Pacific Gas and Electric Company. Prepared by Frontier Energy," 2019.
[4] California Energy Commission, "2025 Energy Code Date and Hourly Factors", 2025. [Online]. Available: https://www.energy.ca.gov/files/2025-energy-code-date-and-hourly- factors
[5] U.S. Energy Information Administration, "Commercial Buildings Energy Consumption Survey (CBECS)", 2018. [Online]. Available: https://www.eia.gov/consumption/commercial/ [6] California Energy Commission, "Clean Energy and Pollution Reduction Act - SB 350", 2019. [Online]. Available: https://www.energy.ca.gov/rules-and-regulations/energy-suppliers- reporting/clean-energy-and-pollution-reduction-act-sb-350 [7] Illinois Statewise Technical Reference Manual, "Volume 2: Commercial and Industrial Measures", 2024. [Online]. Available: https://icc.illinois.gov/downloads/public/il-trm-12/IL- TRM_Effective_010124_v12.0_Vol_2_C_and_I_09222023_FINAL_clean.pdf. [8] City of Palo Alto, "City of Palo Alto Monthly Gas Volumetric and Service Charges", 2020. [Online]. Available:
https://www.paloalto.gov/files/assets/public/v/29/utilities/business/business-rates/monthly- gas-volumetric-and-service-charges-commercial.pdf
[9] California Energy Commission, "2025 Nonresidential HVAC Heat Pump Baseline Report," 2024.
2025 Nonresidential Alterations Reach Code Study 39
2025/07/07
9 Appendices
9.1 Map of California Climate Zones
Climate zone geographical boundaries are depicted in Figure 6. Map of California climate zones. The map in Figure 6. Map of California climate zones. along with a zip-code search directory is available at:
https://ww2.energy.ca.gov/maps/renewable/building_climate_zones.html Figure 6. Map of California climate zones.
2025 Nonresidential Alterations Reach Code Study 40
2025/07/07
9.2 Mixed-Fuel Baseline Energy Figures
Table 20. Medium Retail: Existing Mixed-Fuel Baseline 1980 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 362,829 3,411 $129,201 $6,796 $135,996 41
CZ2 PG&E 440,689 2,431 $162,498 $4,956 $167,454 39
CZ3 PG&E 405,363 1,690 $147,666 $3,423 $151,089 33
CZ4 PG&E 479,116 2,287 $176,888 $4,726 $181,613 40
CZ4-2 CPAU 479,116 2,287 $104,157 $6,375 $110,532 40
CZ5 PG&E 399,754 1,599 $148,036 $3,215 $151,252 32
CZ5-2 SCG 399,754 1,599 $148,036 $2,436 $150,473 32
CZ6 SCE 427,133 590 $114,657 $1,041 $115,698 28
CZ7 SDG&E 435,608 435 $160,261 $623 $160,884 27
CZ8 SCE 498,649 656 $139,534 $1,147 $140,681 31
CZ9 SCE 496,146 846 $140,014 $1,420 $141,434 32
CZ10 SDG&E 518,627 826 $192,271 $1,083 $193,353 33
CZ10-2 SCE 518,627 826 $144,216 $1,388 $145,604 33
CZ11 PG&E 511,565 2,767 $186,733 $5,736 $192,469 44
CZ12 PG&E 471,069 2,466 $172,369 $5,121 $177,490 40
CZ12-2 SMUD 471,069 2,466 $80,619 $5,121 $85,739 40
CZ13 PG&E 524,977 1,865 $190,257 $3,959 $194,217 39
CZ14 SDG&E 518,931 2,349 $180,950 $2,873 $183,824 42
CZ14-2 SCE 518,931 2,349 $135,571 $3,350 $138,920 42
CZ15 SCE 660,960 448 $174,838 $844 $175,682 37
CZ16 PG&E 444,960 4,278 $158,233 $8,542 166,775 51
2025 Nonresidential Alterations Reach Code Study 41
2025/07/07
Table 21. Medium Retail: Existing Mixed-Fuel Baseline 1990 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 337,880 2,543 $119,821 $5,120 $124,941 35
CZ2 PG&E 405,987 1,667 $149,136 $3,384 $152,520 33
CZ3 PG&E 370,768 1,094 $135,276 $2,258 $137,534 28
CZ4 PG&E 435,229 1,559 $160,056 $3,203 $163,258 33
CZ4-2 CPAU 435,229 1,559 $94,425 $4,945 $99,370 33
CZ5 PG&E 378,344 1,033 $139,394 $2,123 $141,517 28
CZ5-2 SCG 378,344 1,033 $139,394 $1,681 $141,075 28
CZ6 SCE 405,100 325 $107,392 $656 $108,048 25
CZ7 SDG&E 408,992 233 $148,909 $390 $149,299 25
CZ8 SCE 458,178 410 $122,006 $785 $122,792 28
CZ9 SCE 456,026 560 $122,445 $1,001 $123,446 29
CZ10 SDG&E 472,282 564 $173,098 $779 $173,876 29
CZ10-2 SCE 472,282 564 $125,599 $1,007 $126,606 29
CZ11 PG&E 458,080 1,808 $166,630 $3,726 $170,356 36
CZ12 PG&E 426,105 1,613 $155,174 $3,334 $158,508 33
CZ12-2 SMUD 426,105 1,613 $72,021 $3,425 $75,446 33
CZ13 PG&E 464,002 1,248 $167,727 $2,623 $170,350 33
CZ14 SDG&E 459,171 1,609 $159,827 $2,007 $161,834 34
CZ14-2 SCE 459,171 1,609 $118,811 $2,422 $121,233 34
CZ15 SCE 550,370 250 $141,683 $551 $142,234 30
CZ16 PG&E 406,009 3,099 $144,458 $6,244 $150,702 42
2025 Nonresidential Alterations Reach Code Study 42
2025/07/07
Table 22. Medium Retail: Existing Mixed-Fuel Baseline 2000 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 331,055 2,964 $116,618 $5,889 $122,507 37
CZ2 PG&E 368,892 2,133 $133,976 $4,359 $138,335 33
CZ3 PG&E 347,589 1,472 $125,426 $2,982 $128,409 29
CZ4 PG&E 389,542 2,098 $141,959 $4,340 $146,299 34
CZ4-2 CPAU 389,542 2,098 $84,047 $6,003 $90,050 34
CZ5 PG&E 352,283 1,414 $128,191 $2,841 $131,031 29
CZ5-2 SCG 352,283 1,414 $128,191 $2,194 $130,384 29
CZ6 SCE 367,634 518 $94,579 $934 $95,513 24
CZ7 SDG&E 370,947 404 $132,002 $587 $132,589 24
CZ8 SCE 407,793 625 $106,172 $1,101 $107,273 27
CZ9 SCE 407,765 825 $106,932 $1,388 $108,320 28
CZ10 SDG&E 414,731 658 $148,951 $886 $149,837 27
CZ10-2 SCE 414,731 658 $107,541 $1,142 $108,683 27
CZ11 PG&E 418,772 2,167 $151,246 $4,529 $155,775 36
CZ12 PG&E 391,670 1,996 $141,560 $4,177 $145,738 34
CZ12-2 SMUD 391,670 1,996 $65,293 $4,177 $69,470 34
CZ13 PG&E 424,029 1,561 $152,401 $3,249 $155,650 33
CZ14 SDG&E 415,063 2,050 $142,703 $2,522 $145,226 35
CZ14-2 SCE 415,063 2,050 $105,480 $2,980 $108,459 35
CZ15 SCE 489,705 344 $124,170 $689 $124,860 28
CZ16 PG&E 378,759 3,736 $133,970 $7,450 $141,421 44
2025 Nonresidential Alterations Reach Code Study 43
2025/07/07
Table 23. Medium Retail: Existing Mixed-Fuel FDD Baseline 1980 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E
CZ2 PG&E 454,429 2,431 $166,955 $4,957 $171,911 39
CZ3 PG&E 410,069 1,718 $149,667 $3,477 $153,144 33
CZ4 PG&E 493,340 2,268 $181,340 $4,689 $186,029 40
CZ4-2 CPAU 493,340 2,268 $107,191 $6,337 $113,528 40
CZ5 PG&E 420,845 1,595 $153,940 $3,208 $157,147 33
CZ5-2 SCG 420,845 1,595 $153,940 $2,431 $156,371 33
CZ6 SCE 453,474 595 $116,544 $1,048 $117,591 29
CZ7 SDG&E 465,024 444 $165,911 $633 $166,545 29
CZ8 SCE 520,726 650 $142,311 $1,138 $143,449 32
CZ9 SCE 515,751 842 $142,484 $1,413 $143,897 33
CZ10 SDG&E 535,283 820 $194,944 $1,076 $196,019 34
CZ10-2 SCE 535,283 820 $146,313 $1,380 $147,693 34
CZ11 PG&E 521,719 2,769 $189,851 $5,734 $195,584 44
CZ12 PG&E 484,282 2,462 $176,675 $5,112 $181,787 41
CZ12-2 SMUD 484,282 2,462 $82,124 $5,112 $87,236 41
CZ13 PG&E 538,085 1,868 $194,411 $3,961 $198,371 40
CZ14 SDG&E 530,607 2,345 $184,263 $2,868 $187,132 42
CZ14-2 SCE 530,607 2,345 $137,213 $3,344 $140,557 42
CZ15 SCE 671,269 450 $176,129 $846 $176,975 37
CZ16 PG&E 459,029 4,288 $163,083 $8,558 $171,641 51
2025 Nonresidential Alterations Reach Code Study 44
2025/07/07
Table 24. Medium Retail: Existing Mixed-Fuel FDD Baseline 1990 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 343,733 2,534 $123,444 $5,104 $128,548 35
CZ2 PG&E 418,947 1,649 $153,333 $3,350 $156,683 33
CZ3 PG&E 390,900 1,085 $141,990 $2,241 $144,231 29
CZ4 PG&E 447,994 1,542 $164,034 $3,168 $167,202 33
CZ4-2 CPAU 447,994 1,542 $97,159 $4,911 $102,070 33
CZ5 PG&E 398,742 1,007 $145,166 $2,075 $147,241 29
CZ5-2 SCG 398,742 1,007 $145,166 $1,645 $146,811 29
CZ6 SCE 431,799 326 $109,424 $657 $110,081 26
CZ7 SDG&E 437,821 238 $154,396 $395 $154,790 26
CZ8 SCE 477,680 408 $124,303 $782 $125,085 28
CZ9 SCE 473,486 559 $124,510 $999 $125,510 29
CZ10 SDG&E 487,233 562 $175,501 $775 $176,276 30
CZ10-2 SCE 487,233 562 $127,366 $1,002 $128,368 30
CZ11 PG&E 466,851 1,808 $169,374 $3,722 $173,095 36
CZ12 PG&E 437,293 1,611 $158,828 $3,326 $162,154 33
CZ12-2 SMUD 437,293 1,611 $73,304 $3,417 $76,721 33
CZ13 PG&E 474,897 1,252 $171,129 $2,626 $173,755 33
CZ14 SDG&E 469,042 1,603 $162,673 $2,001 $164,674 35
CZ14-2 SCE 469,042 1,603 $120,229 $2,415 $122,645 35
CZ15 SCE 559,124 255 $142,698 $558 $143,255 31
CZ16 PG&E 418,885 3,099 $148,862 $6,244 $155,106 42
2025 Nonresidential Alterations Reach Code Study 45
2025/07/07
Table 25. Medium Retail: Existing Mixed-Fuel FDD Baseline 2000 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 334,133 2,955 $118,836 $5,874 $124,710 37
CZ2 PG&E 376,400 2,109 $136,465 $4,316 $140,781 34
CZ3 PG&E 359,362 1,460 $129,290 $2,962 $132,252 29
CZ4 PG&E 397,033 2,072 $144,339 $4,293 $148,632 34
CZ4-2 CPAU 397,033 2,072 $85,661 $5,953 $91,615 34
CZ5 PG&E 364,695 1,383 $131,734 $2,785 $134,519 29
CZ5-2 SCG 364,695 1,383 $131,734 $2,151 $133,885 29
CZ6 SCE 384,244 510 $96,104 $923 $97,028 25
CZ7 SDG&E 388,971 403 $135,619 $585 $136,205 25
CZ8 SCE 419,809 621 $107,602 $1,094 $108,696 27
CZ9 SCE 418,105 817 $108,172 $1,377 $109,548 28
CZ10 SDG&E 423,876 653 $150,475 $880 $151,355 27
CZ10-2 SCE 423,876 653 $108,644 $1,134 $109,778 27
CZ11 PG&E 424,497 2,169 $153,029 $4,528 $157,557 36
CZ12 PG&E 398,822 1,988 $143,941 $4,161 $148,103 34
CZ12-2 SMUD 398,822 1,988 $66,124 $4,161 $70,285 34
CZ13 PG&E 431,259 1,566 $154,654 $3,252 $157,906 33
CZ14 SDG&E 421,138 2,041 $144,521 $2,512 $147,033 35
CZ14-2 SCE 421,138 2,041 $106,356 $2,968 $109,324 35
CZ15 SCE 495,422 347 $124,838 $693 $125,531 29
CZ16 PG&E 387,411 3,733 $136,960 $7,444 $144,405 44
2025 Nonresidential Alterations Reach Code Study 46
2025/07/07
Table 26. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 1980 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 330,146 3,634 $117,538 $7,104 $125,029 40
CZ2 PG&E 386,517 3,028 $142,626 $6,061 $148,784 39
CZ3 PG&E 350,383 2,205 $128,615 $4,472 $132,777 33
CZ4 PG&E 422,921 2,793 $156,411 $5,683 $162,326 39
CZ4-2 CPAU 422,921 2,793 $91,914 $7,369 $99,283 39
CZ5 PG&E 357,588 2,112 $133,079 $4,244 $137,183 32
CZ5-2 SCG 357,588 2,112 $133,079 $3,085 $136,164 32
CZ6 SCE 380,747 850 $102,047 $1,415 $103,121 26
CZ7 SDG&E 390,599 669 $144,977 $891 $145,908 26
CZ8 SCE 438,518 930 $119,049 $1,532 $120,395 29
CZ9 SCE 437,803 1,166 $120,876 $1,857 $122,464 31
CZ10 SDG&E 458,750 1,148 $173,011 $1,453 $174,689 31
CZ10-2 SCE 458,750 1,148 $125,076 $1,826 $126,902 31
CZ11 PG&E 456,417 3,295 $167,066 $6,765 $174,237 43
CZ12 PG&E 416,712 2,963 $152,974 $6,076 $159,597 40
CZ12-2 SMUD 416,712 2,963 $71,498 $6,076 $77,574 40
CZ13 PG&E 466,474 2,324 $169,400 $4,867 $174,919 38
CZ14 SDG&E 470,503 2,871 $165,898 $3,474 $170,600 41
CZ14-2 SCE 470,503 2,871 $122,830 $3,959 $126,790 41
CZ15 SCE 577,811 677 $153,714 $1,182 $154,982 33
CZ16 PG&E 399,719 4,978 $144,332 $9,824 $156,858 51
2025 Nonresidential Alterations Reach Code Study 47
2025/07/07
Table 27. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 1990 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 322,594 2,731 $114,844 $5,381 $120,348 35
CZ2 PG&E 379,888 1,773 $139,052 $3,542 $142,545 32
CZ3 PG&E 344,512 1,518 $125,878 $3,054 $128,693 29
CZ4 PG&E 395,103 1,991 $145,396 $4,119 $149,382 33
CZ4-2 CPAU 395,103 1,991 $85,705 $5,794 $91,498 33
CZ5 PG&E 350,123 1,464 $129,954 $2,918 $132,715 29
CZ5-2 SCG 350,123 1,464 $129,954 $2,262 $132,217 29
CZ6 SCE 375,743 527 $99,724 $947 $100,368 24
CZ7 SDG&E 378,545 412 $138,486 $595 $138,989 24
CZ8 SCE 420,056 609 $113,165 $1,076 $113,920 27
CZ9 SCE 418,250 791 $113,537 $1,338 $114,473 28
CZ10 SDG&E 431,007 806 $161,040 $1,058 $162,204 28
CZ10-2 SCE 431,007 806 $116,142 $1,358 $117,500 28
CZ11 PG&E 425,508 2,241 $155,289 $4,668 $159,824 36
CZ12 PG&E 402,141 1,692 $146,265 $3,461 $149,864 32
CZ12-2 SMUD 402,141 1,692 $67,348 $3,552 $70,900 32
CZ13 PG&E 429,557 1,578 $155,836 $3,276 $159,386 32
CZ14 SDG&E 439,219 1,630 $153,147 $2,024 $155,666 33
CZ14-2 SCE 439,219 1,630 $112,586 $2,450 $115,036 33
CZ15 SCE 508,300 345 $129,173 $692 $129,792 29
CZ16 PG&E 375,366 3,762 $135,625 $7,477 $144,980 43
2025 Nonresidential Alterations Reach Code Study 48
2025/07/07
Table 28. Medium Retail: Mixed-Fuel SZAC Code Minimum Baseline 2000 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 321,233 3,071 $113,854 $5,975 $120,295 36
CZ2 PG&E 361,254 2,169 $131,810 $4,369 $136,118 33
CZ3 PG&E 330,971 1,926 $120,584 $3,914 $124,282 30
CZ4 PG&E 370,393 2,535 $136,586 $5,163 $141,648 35
CZ4-2 CPAU 370,393 2,535 $80,268 $6,862 $87,130 35
CZ5 PG&E 335,034 1,890 $123,792 $3,800 $127,347 30
CZ5-2 SCG 335,034 1,890 $123,792 $2,817 $126,609 30
CZ6 SCE 355,508 762 $93,744 $1,285 $94,620 25
CZ7 SDG&E 358,170 627 $130,391 $842 $131,108 24
CZ8 SCE 395,918 856 $105,868 $1,436 $106,879 27
CZ9 SCE 395,348 1,093 $106,814 $1,763 $108,063 28
CZ10 SDG&E 405,367 905 $149,399 $1,169 $150,412 27
CZ10-2 SCE 405,367 905 $107,416 $1,498 $108,914 27
CZ11 PG&E 417,708 2,183 $151,320 $4,538 $155,852 35
CZ12 PG&E 387,330 2,018 $140,877 $4,181 $145,153 33
CZ12-2 SMUD 387,330 2,018 $65,115 $4,181 $69,296 33
CZ13 PG&E 423,172 1,594 $152,705 $3,294 $156,178 32
CZ14 SDG&E 414,645 2,014 $144,695 $2,469 $147,726 34
CZ14-2 SCE 414,645 2,014 $106,914 $2,936 $109,850 34
CZ15 SCE 486,731 447 $123,568 $843 $124,277 28
CZ16 PG&E 369,114 3,405 $132,583 $6,739 $141,949 40
2025 Nonresidential Alterations Reach Code Study 49
2025/07/07
Table 29. Small Office: Existing Mixed-Fuel Baseline 1980 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 75,261 778 $31,724 $1,597 $33,321 9
CZ2 PG&E 100,788 373 $42,553 $834 $43,387 8
CZ3 PG&E 91,453 248 $38,556 $589 $39,145 7
CZ4 PG&E 110,793 350 $46,904 $797 $47,701 9
CZ4-2 CPAU 110,793 350 $24,048 $2,569 $26,618 9
CZ5 PG&E 91,961 267 $38,743 $622 $39,366 7
CZ5-2 SCG 91,961 267 $38,743 $569 $39,312 7
CZ6 SCE 99,673 67 $26,098 $278 $26,376 6
CZ7 SDG&E 101,642 44 $35,577 $171 $35,747 7
CZ8 SCE 114,050 81 $31,431 $299 $31,730 7
CZ9 SCE 114,398 105 $31,901 $334 $32,235 8
CZ10 SDG&E 118,460 102 $43,632 $239 $43,871 8
CZ10-2 SCE 118,460 102 $33,047 $329 $33,376 8
CZ11 PG&E 117,108 425 $49,743 $950 $50,693 10
CZ12 PG&E 106,223 394 $44,995 $888 $45,883 9
CZ12-2 SMUD 106,223 394 $20,060 $888 $20,948 9
CZ13 PG&E 119,384 287 $50,724 $680 $51,404 9
CZ14 SDG&E 118,563 427 $41,525 $621 $42,146 10
CZ14-2 SCE 118,563 427 $32,206 $809 $33,015 10
CZ15 SCE 152,540 56 $40,238 $263 $40,501 9
CZ16 PG&E 103,301 832 $43,580 $1,716 $45,296 11
2025 Nonresidential Alterations Reach Code Study 50
2025/07/07
Table 30. Small Office: Existing Mixed-Fuel Baseline 1990 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 72,021 438 $30,381 $953 $31,334 7
CZ2 PG&E 89,947 235 $37,988 $565 $38,553 7
CZ3 PG&E 83,347 147 $35,157 $392 $35,549 6
CZ4 PG&E 97,565 217 $41,303 $534 $41,837 7
CZ4-2 CPAU 97,565 217 $21,160 $2,309 $23,469 7
CZ5 PG&E 83,667 154 $35,270 $404 $35,674 6
CZ5-2 SCG 83,667 154 $35,270 $406 $35,675 6
CZ6 SCE 90,245 30 $23,698 $224 $23,921 6
CZ7 SDG&E 92,140 19 $32,220 $141 $32,362 6
CZ8 SCE 102,681 40 $28,184 $239 $28,423 6
CZ9 SCE 103,712 59 $28,728 $266 $28,994 7
CZ10 SDG&E 107,528 56 $39,322 $185 $39,507 7
CZ10-2 SCE 107,528 56 $29,772 $262 $30,034 7
CZ11 PG&E 100,240 236 $42,565 $573 $43,138 7
CZ12 PG&E 91,849 222 $38,909 $545 $39,454 7
CZ12-2 SMUD 91,849 222 $17,610 $545 $18,156 7
CZ13 PG&E 101,569 159 $43,140 $422 $43,563 7
CZ14 SDG&E 102,817 234 $36,438 $396 $36,835 7
CZ14-2 SCE 102,817 234 $28,177 $526 $28,703 7
CZ15 SCE 123,910 21 $33,089 $212 $33,301 7
CZ16 PG&E 92,250 482 $38,948 $1,041 $39,989 9
2025 Nonresidential Alterations Reach Code Study 51
2025/07/07
Table 31. Small Office: Existing Mixed-Fuel Baseline 2000 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 68,456 493 $28,883 $1,055 $29,938 7
CZ2 PG&E 79,179 293 $33,447 $677 $34,123 7
CZ3 PG&E 76,464 208 $32,260 $510 $32,770 6
CZ4 PG&E 88,126 296 $37,294 $691 $37,986 7
CZ4-2 CPAU 88,126 296 $19,064 $2,464 $21,528 7
CZ5 PG&E 76,492 220 $32,254 $532 $32,786 6
CZ5-2 SCG 76,492 220 $32,254 $501 $32,755 6
CZ6 SCE 81,829 50 $21,808 $254 $22,062 5
CZ7 SDG&E 83,863 33 $29,630 $158 $29,788 5
CZ8 SCE 91,235 65 $24,986 $276 $25,263 6
CZ9 SCE 92,122 90 $25,427 $313 $25,739 6
CZ10 SDG&E 89,493 67 $32,760 $198 $32,957 6
CZ10-2 SCE 89,493 67 $24,833 $278 $25,111 6
CZ11 PG&E 91,473 288 $38,808 $675 $39,483 7
CZ12 PG&E 84,414 277 $35,745 $655 $36,400 7
CZ12-2 SMUD 84,414 277 $16,165 $655 $16,820 7
CZ13 PG&E 92,371 201 $39,199 $507 $39,706 7
CZ14 SDG&E 93,481 297 $32,954 $470 $33,424 7
CZ14-2 SCE 93,481 297 $25,404 $619 $26,023 7
CZ15 SCE 110,070 30 $29,189 $224 $29,413 7
CZ16 PG&E 86,242 553 $36,412 $1,176 $37,588 9
2025 Nonresidential Alterations Reach Code Study 52
2025/07/07
Table 30. Small Office: Mixed-Fuel SZAC Code Minimum Baseline 1980 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 74,317 717 $31,326 $1,478 $32,805 9
CZ2 PG&E 84,591 488 $35,754 $1,049 $36,803 8
CZ3 PG&E 78,044 125 $32,919 $338 $33,257 6
CZ4 PG&E 94,705 166 $40,082 $420 $40,502 7
CZ4-2 CPAU 94,705 166 $20,479 $2,208 $22,687 7
CZ5 PG&E 78,443 135 $33,060 $351 $33,411 6
CZ5-2 SCG 78,443 135 $33,060 $374 $33,434 6
CZ6 SCE 83,582 43 $23,243 $242 $23,485 5
CZ7 SDG&E 85,477 31 $31,621 $155 $31,776 5
CZ8 SCE 96,775 48 $26,998 $250 $27,248 6
CZ9 SCE 97,201 62 $27,298 $271 $27,569 6
CZ10 SDG&E 100,456 63 $37,125 $193 $37,318 6
CZ10-2 SCE 100,456 63 $28,164 $271 $28,436 6
CZ11 PG&E 102,343 218 $43,454 $531 $43,985 8
CZ12 PG&E 92,336 198 $39,102 $488 $39,590 7
CZ12-2 SMUD 92,336 198 $17,582 $488 $18,070 7
CZ13 PG&E 103,162 156 $43,841 $411 $44,252 7
CZ14 SDG&E 102,851 511 $35,742 $719 $36,460 9
CZ14-2 SCE 102,851 511 $27,774 $931 $28,705 9
CZ15 SCE 121,320 123 $32,905 $362 $33,267 7
CZ16 PG&E 88,974 992 $37,598 $2,014 $39,612 11
2025 Nonresidential Alterations Reach Code Study 53
2025/07/07
Table 32. Small Office: Mixed-Fuel SZAC Code Minimum Baseline 1990 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 72,012 430 $30,378 $937 $31,315 7
CZ2 PG&E 88,161 235 $37,233 $565 $37,798 7
CZ3 PG&E 82,180 0 $34,654 $0 $34,654 5
CZ4 PG&E 96,068 0 $40,621 $0 $40,621 6
CZ4-2 CPAU 96,068 0 $20,735 $0 $20,735 6
CZ5 PG&E 82,723 0 $34,858 $0 $34,858 5
CZ5-2 SCG 82,723 0 $34,858 $0 $34,858 5
CZ6 SCE 88,041 0 $23,392 $0 $23,392 5
CZ7 SDG&E 89,827 0 $31,698 $0 $31,698 6
CZ8 SCE 88,742 30 $24,858 $224 $25,082 5
CZ9 SCE 89,591 41 $25,393 $239 $25,632 6
CZ10 SDG&E 92,812 42 $34,544 $168 $34,712 6
CZ10-2 SCE 92,812 42 $26,132 $240 $26,372 6
CZ11 PG&E 98,184 0 $41,613 $0 $41,613 6
CZ12 PG&E 90,993 0 $38,498 $0 $38,498 6
CZ12-2 SMUD 90,993 0 $17,003 $0 $17,003 6
CZ13 PG&E 98,807 0 $41,898 $0 $41,898 6
CZ14 SDG&E 99,107 232 $34,189 $394 $34,583 7
CZ14-2 SCE 99,107 232 $26,343 $523 $26,866 7
CZ15 SCE 115,611 0 $30,127 $0 $30,127 7
CZ16 PG&E 91,003 471 $38,419 $1,019 $39,438 9
2025 Nonresidential Alterations Reach Code Study 54
2025/07/07
Table 32. Small Office: Mixed-Fuel SZAC Code Minimum Baseline 2000 CZ Utility
Annual
Electricity
Consumption
(kWh)
Annual
Natural Gas
Consumption
(Therms)
Annual
Electricity
Cost
Annual
Natural
Gas
Cost
Total
Annual
Utility
Cost
Annual
GHG
Emissions
(mtons)
CZ1 PG&E 68,453 484 $28,882 $1,038 $29,920 7
CZ2 PG&E 79,039 288 $33,386 $666 $34,052 6
CZ3 PG&E 76,443 204 $32,251 $502 $32,753 6
CZ4 PG&E 87,575 291 $37,051 $680 $37,731 7
CZ4-2 CPAU 87,575 291 $18,925 $2,454 $21,379 7
CZ5 PG&E 76,461 216 $32,241 $524 $32,765 6
CZ5-2 SCG 76,461 216 $32,241 $495 $32,736 6
CZ6 SCE 81,803 49 $21,763 $252 $22,016 5
CZ7 SDG&E 83,831 33 $29,562 $158 $29,720 5
CZ8 SCE 89,680 67 $24,461 $279 $24,740 6
CZ9 SCE 90,572 92 $24,860 $315 $25,175 6
CZ10 SDG&E 88,870 65 $32,096 $196 $32,292 6
CZ10-2 SCE 88,870 65 $24,294 $276 $24,570 6
CZ11 PG&E 90,527 282 $38,386 $665 $39,050 7
CZ12 PG&E 83,984 272 $35,554 $645 $36,198 7
CZ12-2 SMUD 83,984 272 $15,937 $645 $16,582 7
CZ13 PG&E 91,394 198 $38,761 $500 $39,260 7
CZ14 SDG&E 92,520 292 $32,310 $464 $32,774 7
CZ14-2 SCE 92,520 292 $24,839 $611 $25,450 7
CZ15 SCE 107,550 29 $28,186 $224 $28,410 6
CZ16 PG&E 85,337 542 $36,030 $1,152 $37,182 9
9.3 Long-Term Systemwide Cost (LSC) Impacts
This section compared LSC impacts of efficiency measure SZAC packages with SZHP Code Min package. These results help inform the energy-equivalency of the packages being analyzed.
9.3.1 Small Office
Figure 7 shows the LSC impacts results of the MF-EFF package compared to the HP code min package. The MF -EFF package for Small Office prototype includes window film and lighting retrofit measures where they have positive LSC impacts and are cost-effective. This package has LSC impacts exceeding the HP code min package in all applicable Climate Zones and vintages. 2025 Nonresidential Alterations Reach Code Study 55
2025/07/07
Figure 7. Small Office LSC Impacts: MF-EFF vs HP
9.3.2 Medium Retail
Figure 8 shows the LSC impacts results of the MF-HRVDCV package compared to the HP code min package. The MF-HRVDCV package for Medium Retail prototype includes DCV and HRV measures .
The package has LSC impacts meeting or exceeding the HP code min package in all Climate Zones and vintages.
Figure 8. Medium Retail LSC Impacts: MF-HRVDCV vs HP
Figure 9 shows the LSC impacts results of the MF-EFF package compared to the HP-DCV. In addition to the HVAC measures, the MF-EFF package for the Medium Retail prototype includes DCV, window film and lighting retrofit measures in Climate Zones where they have positive LSC impacts and are cost-effective. This package has LSC impacts exceeding the HP-DCV in all Climate Zones and vintages.
2025 Nonresidential Alterations Reach Code Study 56
2025/07/07
Figure 9. Medium Retail LSC Impacts: MF-EFF vs HP-DCV
9.4 Utility Rate Schedules
The Reach Codes Team used the CA IOU and POU rate tariffs detailed below to determine the On-Bill savings for each package.
2025 Nonresidential Alterations Reach Code Study 57
2025/07/07
9.4.1 Pacific Gas & Electric
Pacific Gas and
Electric Company·
Revised
Cancelling Revised
Cal. P.U.C. Sheet No.
Cal. P.U.C. Sheet No.
58719-E
58550-E
U 39 Oakland, California
RATES :
Advice
Decision
ELECTRIC SCHEDULE B-1
SMALL GENERAL SERVICE
Sheet 3
Total bundled service charges are calculated using the total rates shown below . Direct Access (DA) and Community Choice Aggregation (CCA) charges shall be calculated in accordance with the paragraph in this rate schedule titled Billing.
Total Bundled Time-of-Use Rates B-1 Rates B1-ST Rates
Total Customer Charge Rates
Customer Charge Single -phase
($ per meter per day)
Customer Charge Poly-phase
($ per meter per day)
Demand Charge (for B1-ST only)
Total Demand Rate (per metered kW/month
assessed from 2:00 p.m. to 11 :00 p.m. only)
Summer
Winter
Total TOU Energy Rates($ per kWh)
Peak Summer
Part-Peak Summer
Off-Peak Summer
Peak Winter
Partial-Peak Winter (for B1-ST only)
Off-Peak Winter
Super Off-Peak Winter
PDP Rates (Consecutive Day and Five-Hour
Event Option)'
PDP Charges($ per kWh)
All Usage During PDP Event
PDP Credits
Energy($ per kWh)
Peak Summer
Part-Peak Summer
• See PDP Detail, section g, for corresponding
reduction in PDP credits and charges if other
option(s) elected.
7382-E Issued by
Shi/pa Ramaiya
$0.32854
S0.82136
$0.49466
$0.44543
S0.42462
$0.41924
S0.40312
$0.38670
S0.60
($0.05841)
(S0.01735)
(I)
(I)
(1)
(I)
(I)
(I)
$0.32854
$0.82136
$8.01
$8.01
$0.52281
$0.38151
$0.33418
$0.42486
$0.39536
$0.30631
$0.28989
(I)
(I)
(I)
(I)
(I)
(I)
(I)
(I)
(I)
(Continued)
Submitted September 30, 2024
Effective October 1, 2024
Vice President
Regulatory Proceedings and Rates
Resolution
2025 Nonresidential Alterations Reach Code Study 58
2025/07/07
Pacific Gas and
Electric Company·
Rev ised
Cancelling Revised
Cal. P.U.C. Sheet No.
Cal. P.U.C. Sheet No.
58721-E
58552-E
u 39 Oakland, California
RATE :
Advice
Decision
ELECTRIC SCHEDULE B-10 Sheet 3
MED IUM GENERAL DEMAND -METERED SERVICE
Total bundled service charges shown on customers ' bills are unbundled according to the component rates shown below . Direct Access (DA) and Community Choice Aggregation (CCA) charges shall be calculated in accordance with the paragraph in this rate schedule tilled Billing .
TOTAL BUNDLED TIME-OF-USE RATES
Secondary Primary Transmission
Voltage Voltage Voltage
Total Customer Charge Rates
Customer Charge $11.51068 (I) $11.51068 (I) $11.51068 (I) ($ per meter per day)
Total Demand Rates{$ [!er kW}
Summer $21.53 (I) $20.84 (I) $14.28 (I)
Winter $21.53 (I) $20.84 (I) $14.28 (I)
Total Energl,'. Rates {$ 11er kWh}
Peak Summer $0.36862 (I) $0.34745 (I) $0.25044 (I)
Part-Peak Summer $0.30694 (I) $0.28915 (I) $0.19370 (I) Off-Peak Summer $0.27437 (I) $0.25832 (I) $0.16363 (I)
Peak Winter $0.29236 (I) $0.27460 (I) $0.19739 (I)
Off-Peak Winter $0.25688 (I) $0.24097 (I) $0.16456 (I)
Super Off-Peak Winter $0.22054 (I) $0.20463 (I) $0.12822 (I) PDP Rates (Consecutive Dal,'. and Five-Hour
Event O[!tion
PDP Charges{$ 11er kWh}
All Usage During PDP Event $0.90 $0.90 $0.90
PDP Credits
Energy ($ per kWh)
Peak Summer ($0.08103) ($0.08103) ($0.08103)
Part-Peak Summer ($0.02807) ($0.02807) ($0.02807)
• See PDP Details, section g, for
corresponding reduction in PDP credits
and charges if other option(s) elected.
(Continued)
7382-E Issued by Submitted Septembe r 30, 2024
Shi/pa Ramaiya
Vice President
Regulatory Proceedings and Rates
Effective October 1, 2024
Resolution
2025 Nonresidential Alterations Reach Code Study 59
2025/07/07
9.4.2 Southern California Edison
E:iEoisoN
_,...,so~ •>n-r:a-.ArlOJ'IIALCan-
Southern Californ ia Edison
Rosemead , Ca liforn ia (U 338-E )
RATES (Cont inued )
En!!tvr ~ • SlkWl1
Fdties ~ OW'R#ldCh¥Qlll •SAW
T~RetadDem.n:ICh.1 198-Mi:W
TllA!e-f'tmJflSeNc.e-W;Jy
Vcbg&Disccul. En!fv, - S.t.Wh
Vol:aO&Drttotn. Demand• SAW
.2J1lillD..l1
Ftom2kV10501CV
From ~1 tv\02191.V
220lV;ind.D;l'lltllt
F~R.-a
From2W1050W
,'b:w't50Wtiutbelbw2201CV
.. ,,..,,
V01tagt0b,ccu11,$l.lmlel"Or, P$;11:~ •$tk'W
Fl'Offl2 t.Vl0 501.V
N!ole50Wtiutbeklw220t.'V
/IJ220 .. V
vcaave, Disc.~ WMtdats (4-9pm) Dam.n:I • SNN
From2 ~'Vll050t'V
"blNtSOWtiutbEttiw220fN
Al2201.V
~AlemaR.Mesllor
~Oaicxvt-~
calllolliaCll'r'«.eOlcffl-$hneW
Trans'
0).0000,)
(IUl0003)
(O.OIXI03)
(D.00003}
(0.00003)
(0.00003}
, _.,
, ......
000000
0.00000
0.00 0.00
0.00 Revised
Cance lling Revised
Schedu le TOU-GS -1
TIME-OF -USE
GENERAL SER VICE
(Continued )
oer
-Oistrbtn'" NOC PPPC' WF< .. -
01lol099( 1) 0.00809 O.ll0009 o..o,a,e(R) 0.00561
"""""'0) 0.00809 .....,. o..o,a,e(R) 0.00!561
001704 (1) 000809 000000 001i 18{Rl 000561
o..o.&099(1) 0.00809 .....,. o.o,a,e(R) 0.00561
0.01704(1) 0.00809 O.ll0009 o.o,a,e(R) 0.00561
0..00524 (1) 0.00809 .....,. o..o,a,e(R) 0.00561
.....
105(1 )
01 (11
0.00 '-"•
0.00000
0.00000
f0..Cl238no>
l'Q.3,4)(1)
(1.32)(1)
(16.65)(1)
(0.08)
(U41(I)
(1.44 1(1)
0.00 0.00
000
100.00-
(95.00)
Cal. PUC Sheet No . 88873-E
Ca l. PUC Sheet No . 88283 -E
Sheet 5
Generauon
D'l\'RA • PUCRF " Totar UG" OWREC'~
0.00000 0.00100 0.0745l( ll 0. 11,880(R) 0.00000
0.00000 0.00100 0.07453(1) 0.10728(R) 0.00000
0.00000 0,00100 0.050Si( I) 007'C3-1 {R) 000000
0.00000 0.00100 0..07•5l{ll 0.11182(A) 0.00000
0.00000 0.00100 0.Cl5068{1J 0.078'M{R) 000000
0.00000 0.00100 0.03973(1) 0.OS90l5(R) 0.00000
O.IXIU8
000050
o ...
19,58{0
4..81 (11 15..7.ol (A'I
000 S.1-4 (R)
o .. ,
0.00000 (OtXl0"81(R)
0.00000 (O.OXl931(R)
to..0238nm (000051'51(R)
{0.l41(1)
(1.321(1)
(Ul.661(1)
(008) (0.20)
( 1.441(1) (0.<17)
( 1.441(1) (OA7)
000 (0.20)
000 (0.<17)
o_oo (0.<1 7)
100.00"
{SUN>)
Represen ts 100% of the discount percentage as shown in the applicab le Special ConditK>n of this Schedu le. '" The ongoing Compelition Transdton Charge (CTC) of $(0.00028) per kWh ,s recovered in lhe UG componenl of Generation . 1 Trans = Transmission and the Transmi ssion Owners Tariff Charge Adjustments (TOTCA) which are FERC appro ved. The TOTCA represents the Transmission Revenue Balancing Accounl Adjustmenl (TRBAA) of $(0.00360) per kWh, Reliab ility Services Balancing Account Adjustmenl (RSBAA) of $(0.00006) per kWh , and Transm iss10n Access Charge Balanc,ng Acco unl Adjustmenl (TAC BAA) of $0.00351 per kWh 2 Distrbtn = Oistnbution
3 NSGC • New System Generation Charge
4 NOC = Nuclear Decomm issioning Charge
5 PPPC = Public Purpose Programs Charge (includes California Alternate Rates for Energy Surcharge where applicable.) 6 WFC = Wildfi re Fund Non-Bypassable Cha~ge. The Wildfire Fund Non-Bypassable Charge supports the Callfomia Wild Ite Fund and is not applicable to exempt Customers pursuant to 0 .19--10-056. 7 PUC RF= The PUC Reimbursement Fee is described in Sched ule RF•E. 8 Tola! = Tolal Delivery Service mies are applicable to Bundled service , Direcl Access (DA) and Commun ily Choice Aggreg alio n serv ice (CCA Service) Customers , excepl DA and CCA Service Customers are not subject to the DWRBC rate component or lhis Schedule but instead pay the DWRBC as provided by Schedule OA.CRS or Schedule CCA-CRS . 9 Generation= The Generalion mies are applicab le only to Bund led Service Customers . See Special Condition below fo r PCIA recovery. 10 DWREC = Department of Wat er Resources (DWR) Energy Credi t - FOf' more information on lhe DWR Energy Credil , see the Bllling Calc ulation Special Conditio n or this Schedule .
11 DWRA = A refund from the Californ ia Departm enl of Water Resources (DWR ) relaling to the purcha se of power during the 2000-2001 energy crisis.
12 The Modified Cost Allocation Mechanism (MCAM} charge recovers the net cost assoc iated 'With system reliability procurement ordered by the CPUC that SCE has procured on behalf of customers whose generation services are provided by certain EJectric Service Providers or Communtty Choice Aggregal ors.
(To be inserted by utility)
Ad vice 5379-E -------------Dec ision
5C9
(Cont inued )
Issued by
Michael Bac kstrom
Vice Presiden t
(To be inserted by Cal. PUC)
Date Sub mitted Sep 27, 2024
Effect ive Oct 1, 2024
Reso lution
2025 Nonresidential Alterations Reach Code Study 60
2025/07/07
Southern Californ ia Edison
Rosemead , California (U 338-E ) Cance lling
Schedule TOU-GS-2
Revised
Revised
Cal. PUC Sheet No.
Cal. PUC Sheet No.
Shee t 4
TIME-OF-USE - GENERAL SERVICE - DEMAND METERED
(Continued )
RATES (Continued)
8888 5-E
88295-E
~"' ra"°"
lllU..el>;iJo.
En.gyet>arge-M.Wh
Fbt..t~Chaf99 •SA.Wh
O2t120 QI O9Jl9P P..CPP
~-W~ {4-Grpm)
·--
F-Z l V W:,~ •v
~50 W bulbelow-2l0 \ V
Al220 t.V
F,om2 l V I000 l V
~SO W bulbeiow-220..V
Al220W
~~w--w~~ -$NW
~....,_R.Mnior
e-;y~ . ....
TOU°"'°'
~Cln.-o.clil-~
oooon o.cpp
Cf'Pe.-en.t9)'~- lo'\-
S....-Cf"Pl~c...ll
On-P.at.o..n..lC...tl •lltt.W
F_,.21.VtOOO t.V
At,o.,,t50 bulbelow220 l V
Al220 t.V
F_,.2 1.V IOOO IIV
Aboi<e50 kV bul below 2lO kV
Al22011 V
-......
.,...,,, .,...,,,
(0.0000, )
(0.00003 ) .,...,,,
- ·
""
0.00 0.00
0.00 000
0.00 0.00
0.00 0.00
0.00 000000
0.00000
0.00000
,n·
0.01~ 7 {1 ) o,..., o""""' 0.018'7{R)
o.01n•<o 0 .0094) 0.- O-01A7{R)
0.017'3tl(I) O.OOM3 0.00000 0.0 1U7(R)
0.0 11U7 {1) 0.0080 000000 001887{R )
o.o,n•<•> 0.00943 0.00000 O.01U7{R)
o.o,e.111(11 O.00M3 0.00000 O.01U7(R)
ZlQ.:J.4 (1)
::!C.71 (1)
U'.18 (1)
2.1, (l)
(~)(A )
(0 42)(1)
(9. 13)(0
(20 .77)(1)
l'O~ )(I)
(6.-48) (1)
( 17. 18 )(1)
{0.00 )
( 1.CM )(I)
(2.."78) (1)
(0.G0030 HJ)
(O~ (I)
(0.01«18 )(0
ioo.oo·
3e.36 4t)
(M.00 )
Represents t00% ot the dIsoounl percentage as shown in tile applicable SpeaaJ CoodrtlOO of Ills Sclledule.
0.0000 •
o.oo,o,
0.0000 ,
o_, .. ..,., ....,.,
The ongoing Competition Transilion Charge (CTC) ol S(0.00029) per kWh io 18COY8fed in the UG component ol Generation.
0.00000 0,00100
0.00000 0.00100
0.00000 D.00100
~00000 0.00100
~00000 o.ocnoo
~ 0.00100
The MaximuTI Available Crd is the capped aeat amoonl (o, CPP Customers dual participalng in othef demand response protJrams. uu· •
O~(l ) 0. 11,WO(RJ 000000
0.0Cl17 1(1) 0. 10'.)0(R) 0.00000
CUllll.13 (1) .__(RJ 000000
0.0IU34 (1) 0.OTne(R) 000000
O.Oei171(1) o..orn:t(R) 0.00000
o..oeo7& (1) 0.tMOt l (R) 0.00000
000 1)7
0.0000,
2311.340)
~A? (I)
1?. 18 (1) 2t..24(R)
2.71 (1) ......
(8..:5) 1;AI
(0. <12)(11 0.00
(9.13)(11 0.00
(20 ,77) (1) 0.00
(0,.30 )(11 l'0,4ij) (RJ
(6.48 )(11 (l . ll ) (R)
( 17 .18) (1) ( 1. l:2) (R)
., ... , {O.l2) (R)
( I.CM J(IJ (0.20 ) (R)
(2.78:J(IJ (0.20J(A)
(0000:)t )(I) (O..OCIC»o' ► ~)
(0.0082ll )(I) (O..oo:207► (A )
(0.01«18 )(1) (0.-002C»14"1)
100..00·
..... ,, ... ,.,
0.,0000
.._ .. ,
(2 1.24 )(R)
Trans = Transmission and lhe Transmission Owners Tariff Charge Adjustments (TOTCA) which are FERC approved. The TOTCA represents the Transmission Revenue Balancing Account Adjustment (TRBAA) of $(.003 60) per kWh, Reliability Se rvices Balancing Account Adjustment (RSBAA) or S(0.00006) per kWh, and Transmission Access Charge Balancing Account Adjustment (TAC BAA) or $0.00351 per kWh. 2 Dislrbln = Distribution
3 NSGC = New System Generation Charge
4 NDC = Nuclear OecommisstOning Charge
5 PPPC = Public Purpose Programs Charge (includes California Alternate Rates for Energy Surcharge where applicable.) 6 W FC = Wildfire Fund Non-Bypassable Charge . The W ildfire Fund Non-Bypassable Charge supports the California Wildfire Fund and is not applicable to exempt Custome rs pursuant to D.19-10-056 . 7 PUCRF = The PUC Reimbursement Fee is described in Schedule RF-E. 8 Total = Total Delivery Service rales are applicable to Bundled Service, Direct Access (DA) and Community Choice Aggregation Service (CCA Service) Customers, except DA and CCA Service Customers are not subject to the DWRBC rate component of this Schedule but instead pay the DWRBC as provided by Schedule DA-CRS or Schedule CCA-CRS. 9 Generat ion = The Generatton rates are applicable only to Bundled Service Customers. See Special condition below for PC IA recovery. 10 DWREC = Department or Water Resources (DWR) Energy Credit - For more information on lhe DWR Energy Credit, see lhe Billing Calculation Special Condition ol lhis Schedule.
11 DWRA = A refund from the California Depa rtment of Water Resources (DWR) relating to the purchase of power during the 2000 -200 1 energy crisis.
12 The Modified Cost Allocation Mechanism (MCAM) charge recovers the net cost associated with system reliability procurement ordered by the CPUC that SCE has procured on behalf or customers wtiose generation services are provided by certain Electric Service Providers or Community Choice Aggregators.
(To be inserted by utility)
Advice 5379-E ------------Decision
(Cont inued )
Issued by
Michael Backstrom
Vice President
(To be inserted by Cal. PUC )
Date Subm itted Sep 27, 2024
Effective Oct 1, 2024
2025 Nonresidential Alterations Reach Code Study 61
2025/07/07
~ EoisoN
,.. , 111 Q .v, ,,._,.,.,,o ~,u.c--,
Southern Californ ia Ed ison
Rosemead , Ca liforn ia (U 338- E)
Revised
Cancelling Revised
Cal. PUC Sheet No. 88900- E
Cal. PUC Sheet No. 883 10-E
Schedule TOU-GS -3 Sheet 3
TIME-OF-USE - GENERAL SERV IC E - DEMAND METERED
(Con tinued )
RA TES (Continued )
Ll'ffl!Verv;:Mlfl ioe
""'
-tn) tn·
Opli,pftQ/OpliqnR:Ctt
~CNtOt-Mwt<i
'"""""''
0 ,0 1&>1 (1) ., .. ,.. 000000 0 .O172:0(R ) o.ooee, 000000 0,00100 O.oe,oQS(I) D, 10008 (R I ....... .. _.._, o.01e?O<•> .,,.,.. 0.00000 0.O1720(A ) 0.0000, 0.00000 0.00100 0.0.UO (l} 0 _006?)(111: ) <LOOOCIO .. _.._, 0.0 1~ (1) 0.007" 000000 0 0 1no tR1 o_, 0 00000 0.001 00 O.b4tt O (ll o.~c11111 0 OOOCIO '"""""''
0.01~ (1) .,,.,.. 000000 o.01no(R 1 0.00&61 0 .00000 0.00100 o.oeioos (I) 007!539 (RI <LCIOOCIO '"""""''
0.0 IOlV (I) .,,.,.. 000000 0.01720(R I
""""'
0-00000 0.00100 0~(1) 007~ (RI <LCIOOCIO
- ·
0.01~1 (1) .,,.,.. 0 .00000 0.01no(R 1
""""'
0-00000 0 .00100 0 .0"7&2 (1) O.Ql09.l ( R ) QOOOCIO
000110
o.oooe,
~~- ~
=:::i•MWof~~ ....
702.22(1)
11i> Ool (I)
=••
22.27 (1)
10.0- (1) Ul.cM III ,..,,'"' ..,.., ~:la-Cl) ...... ,
V,olu,g,tO- ~ • Sll<W
·--
IF'tum2 WV lo~k V
At,o,.,.50k V bull- :2:N) kV
F,_ :l:WIIO ,Oh V
-!IO bull-Z?Ok V
Al 220k V
0.00 0.00
0.00 0.00
0.00 0.00
(Q.31!11(1)
ctM)CII
( Ht,04 1(1)
(0..Xl)(I)
(e.56)(1)
( 10-04 )(()
(0.36) {1)
(1.N}Cll
( Ul.(M )(I)
l'0.2-5)(1) (O..oi2)( A)
~ S&)(I) (O.O?)( AI
(1 0.(M )(I) (Q.N H R I
~Ch-.. WirMWW....S.:,. (.....,_,0...- . M,W
From::t, V 111>50kV
,.._!IOt. V bl.il-Z!Oh V
Al:nl>k V
0.00 0.00
0,00
co. .. ,
(1 10)(1)
CU8)(1)
(0.00) (O. IOH AI
( t 14){l) (0.2,5)( R I
(3.:la-){l) (0...36)(R I
Ft'Offl ::t •V IIOSO~V
-tlOk V bull- 220 kV
Al220 W
OOOOCIO
QOOOCIO
0_00000
(0~)(1)
( 0.0M3e )(I)
( 0.01~ (1)
(0.00020) (1) (O~)(R)
CO.0053e J(II (O.al.."OO)(R}
co..01.s&t,(11 (O.~ ){R)
,,_F_...._ _M V.A.R
GN.»IM-.!lOh V
l50 1tiVor..._
.... .. ., .... . ..,
~.-....-~ ..
~OMo..- - •
~
100.00" 100.00'
~~~~~wt, . ...,..
On,,Pw,,at;O...-C.- - Mtw (1.e-5)
2 3
4 5
6 7
8 9
10 11
12 (ta..22:l(A)
Represents 100% of the discou nt percentage as shown in the applicable Special Condition of this Schedule .
The ongoing Compeli tion Transition Charge (CTC) or $(0.00029) per kWh is recovered in the UG componenl or Generation .
The Maximum Available Credit is the capped credit amou nt for CPP Customers dual participating in other demand response programs Trans= Transmission and the Tran smissio n OWners Tariff Charge Adjustments (TOTCA) which are FERC approved . The TOTCA represent s lhe Transmission Revenue Balanc ing Acco unt Adju stment (TRBAA) of $(0.00360) per kWh , Reliabili ty Services Balancing Account Adju stment (RSBAA) or $(0.00005) per kWh , and Transmission Access Charge Balancing Accounl Adjustment (TACBAA) or $0.00351 per kWh .
Distrbtn = Distrib ution
NSGC = New Syslem Generation Charge
NOC = Nuclea r Decommi ssioning Charge
PPPC = Public Purpose Program s Charge (including California Alternate Rates for Energy Surcharge W'here applicab le.) WFC == Wildfi re Fund Non•Bypassable Charge . The Wildfire Fund Non •Bypassable Charge supports the California Wildfire Fund and is not applicable lo exempt Customers P<,Jrsuant lo 0 .19-10-056 .
PUC RF= The PUC Reimbursement Fee is described in Schedule RF-E .
Total == Tota l Delrvery Seivice rates are applicable to Bundled Service , Direct Access (DA) and Comm unity Choice Aggregation Service (CCA Service) Customers , except DA and CCA Service Customers are not subject lo lhe OWRBC rate compone nt of this Schedule but instead pay the OWRBC as provided by Schedule OA-CRS or Schedule CCA-CRS .
Generation == The Gene ration rates are applicable only to Bund led Service Customers . See Special Condition below for PCIA recovery .
OWREC == Department of Water Resource s (OWR) Energy Credit - For more information on the OWR Energy Credit, see the Billing Calcu lation Special Condition of this Schedule .
OWRA = A refund from lhe Califo rnia Oepartmenl or Water Resou rces (OWR) relaling to the purcha se or Power during the 2000-2001 energy crisis .
The Modified Cost Allocation Mechan ism (MCAM) charge recovers the net cost associated with system reliability procurement orde red by the CPUC that SCE has procured on behalf of customers whose generation services are provided by certain Electric Seivice Provid ers or Community Choice Aggregato rs
(Continued )
(To be inse rted by utility) Issued by
Michael Backstrom
Vice President
(To be inserted by Ca l. PUC )
Date Subm itted Sep 27, 2024 Adv ice 5379-E -------------Dec ision Effect ive Oct 1, 2024 3C9 Resolution
2025 Nonresidential Alterations Reach Code Study 62
2025/07/07
9.4.3 Southern California Gas
SOD~R!"{ CALlFORl IIA GAS COllP . .\J.""I,: Revised CAf... !l.U.C. SHEE'FNO. 62162-G CAf... !l.U.C. SHEE'FNO. 6213 1-G LO.<; . .\NGE1.£S, CALIFORNIA C.o\NCEUNG Revised Schedule No. G-10
OORE OOMMERCLJ\L AND INDUSTRIAL SERVICE
(Jndude s GN-10. G -IOC and GT-10 Rates)
(Continued)
R.I\TES (Continued)
All ~ocurement , Transmission, and Commodity Giarges are billed perthenn.
Tier ll11
Sheet 2
GN- 10:., Applicable to natural gas proc,urement se1Vice t.o non-tesidential core cnst.omers, including se1.-vice not provided under any other rate scbeduile.
Procurement Charge: v
Tiansmission Charge:
Commodity Charge:
G-CPNR .... .... ....... ....... .. 27 .626¢
GPT-10 ........................... H3 .275¢
GN-10 ....................... 140.901¢
27.626¢
66: 41¢
94.36 ¢
27.626¢
35.540¢
63.166¢
GN-1 0C": Core procurement service for previous non-resSidential transportati.on~only customers retnmi.ng to core procurement setvice, inchidiug CAT crnfomer with annual cow,1:imption over 50,000 therms as further de:fined in Schedule No. G-C P.
Procurement Charge: v
Tiansmission Charge:
Commodity Charge:
G-CPNRC ................. . _8.095¢
GPT-10 ............. H3.2 5¢
GN- IOC .................... 141.3 0¢
_8.095¢
66. 4U
94.836¢
28.095
35.540¢
63.635
GT- I 0-': Applicable to non~residential tranq>ertatiou-on1y service inclnding CAT service, as set forth in Special Coudi:tion 13.
Tiansmission Charge: GT-10 ............................. 113.275¢11 66. 41¢11 35.540¢11 11 Tier I rates are applicahle for the fu:st 250 fuerms used per wonfu. Tier II rate,;;. Me appl!icable for usage abO\'e Tier I quantities and up throogh4,167 therms permomh. I ier ID.rates are apphc.able for all usage above4,167 themJs per month. Under tb.i:s schedule, fue winter season shall be defirned as December I through March 31 and the summer sea;;on as April 1 through Noveni.ler 30.
11 11ms cha!rge is appli able for service to Utility Proc.tll'emen! Customers as sho\m in Schedule iNo. G-CP, in the lllllllll.erapproved by D.96-0&-037, and &ubject to cbange,montbly, as set forth in Specill] C-ondi1ion 5. 31 These charges are equal to tire coTe commodity rate less the foMowmg two components as approved in D.97-04- 082: (I) the weighted average ooot of gas; and (2) fue oore brokerage fee. (Footnotes. can±imre ne.'\Jt page.)
{TO, BE IN'SERTED BY ITTILJiYJ
AUVIC£ LETTER NO. 6369~G
OECISIONNO. D20-02-045 ; D24-
1H1 07-013
Continued
ISSUBOSY
Dao Skop e~
Senior Vi President
Re,gula1Dry Affai"s
0 BE INSEITTIEID SY CAL. PUG.I
SUBMITTED Sep 26 2024
EFFECTIVE Oct I, 2024
RESOlUTION NO. -------
R
R
R
R
R
2025 Nonresidential Alterations Reach Code Study 63
2025/07/07
9.4.4 San Diego Gas & Electric
sos/' ..,..'E
San Diego Gas & Electric Comr,any
San Diego, California
RATES• /Conti nued\
Description - AL-TOU Transm
Enemi Q!a,~ ,~Wh}
Qa-ei:lals - Summi:lc
Secondary (0.01945)
Primary (0,01945)
Secondary Substalion (0.01945)
Primary Substation (0.01945)
Transmission (0,01945)
Off-Peak - Summer
Secondary (0,01945)
Primary (0.01945)
Secondary Substation (0.01945)
Primary Substation (0,01945)
Transmission (0,01945)
SU!!!!• Off-Peak
Secondary (0.01945)
Primary (0.01945)
Secondary Substation (0,01945)
Primary Substation (0,01945)
Transmission (0.01945)
Qn-Peak - Winter
Secondary (0,01945)
Primary (0,01945)
Secondary Substalion (0,01945)
Primary Substation (0.01945)
Transmission (0.01945)
Qf!-PHk - JMn!!!f
Secondary (0.01945)
Primary (0.01945)
Secondary Substation (0.01945)
Primary Substation (0.01945)
Transmission (0,01945)
~ll!l cQ!l-e~at
Secondary (0,01945)
Primary (0.01945)
Secondary Substation (0.01945)
Primary SUbstation (0,01945)
Transmission (0.01945)
Revised Cal. P.U.C. S heet No. 62379-E
Canceling Revised Cal PUC Sheet No .. 61921-E
SCHEDULE AL-TOU Sheet4
GENERAL SERVICE - TIME METERED
Dlstr PPP ND CTC LGC RS TRAC UDC
Total
0.00177 0.01789 I 0.00007 0,00047 0.01798 0.00001 0,01874
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00177 0.01789 I 0.00007 0,00047 0.01798 0.00001 0.01874
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0,00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0,00177 0.01789 I 0,00007 0,00047 0.01798 0.00001 0,01874 0,00177 0.01789 I 0.00007 0,00047 0.01798 0.00001 0,01874 0,00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
0,00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0,00177 0.01789 I 0.00007 0,00047 0.01798 0.00001 0,01874
0.00177 0.01789 I 0.00007 0.00047 0.01798 0.00001 0.01874 0,00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0,01717
0.00130 0.01726 I 0.00007 0.01798 0.00001 0.01717
Notes: Transmission Energy charges include Ille Transmission Revenue Balancing Accounl Adjuslment (TRBAA) of S(0.00289) per kWh and the Transmission Access Charge Balancing Account Acjuslmenl (TACBAA) of S(0.01656) per kWh. The PPP rale is composed of Energy and Demand charges. For all voltage levels, the PPP Energy charges irldudes Low Income PPP rate (LI-PPP) SQ.01515/kWh, Non- low Income PPP rate (Non-LI-PPP) S0.00211/kWh (pursuant to PU Code Seciion 399.8, the Non-LI-PPP rate may not exceed January 1, 2000 levels). For Secondary and PYimary voltage levels, the PPP Energy charge also indudles CalJornia Solar Initiative rate (CSI) of $(0.00045)11<Wh and Self-Generation lnoentive Program rate {SGIP) S 0.00108 /kWh. For Secondary Substation, Prrnary Substation and Transmission voltage levels, the PPP rate irlcludes Demand charges for CSI of S{0.16Y"Wand SGIP of SQ.39 /kW. "These rates are nol applicable to TOU Period Grandfalhering Eligible Customer Generalors, please refer to SC 20 for applicable rates. {Continued)
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
I
4C8 Issued by Submitted See 30, 2024
Advice Ur. No. 4507-E Dan Skopec Effective Oct 1, 2024
Senior Vice President
Decision No. 0 .24-07-013 Regulatory Affairs Resolution No. 2025 Nonresidential Alterations Reach Code Study 64
2025/07/07
sos/' _'E
San Diego Gas & Electric Company
San Diego, CalHomla
Revised Cal. P.U.C. Sheet No.
Canceling Revised Cal P U C Sheet No
SCHEDULE TOU-A
GENERAL SERVICE - TIME OF USE SERVICE
SPECIAL CONDITIONS (cont inued )
TO!,.l GRANDFATHERING RATES
Description Transm 0lstr PPP NO CTC LGC TOU-A
Ba.sic Service Fae ll/m
C:.W-ondarv
0-5kW 11.45
>5-20 kW 18.32
>20-50kW 34.35
>50kW 85.87
~
0-5kW 11.45
>5-20kW 18.32
>20-50kW 34.35
>50kW 85.87
•norov Charaos ,t"'Wh
On-Peak - Summer
Secondary 0.0299 1 0.15287 I 0.01696 I lo.00007 0.00052 0.01760 Primary 0.0299 1 0.15209 I 0.01696 I lo.00007 0.00052 0.01760 Semi-Peak. Summer
Secondary 0.0299 1 0.15287 I 0.01696 I io.00007 0.00052 0.01760 Primary 0.0299 1 0.15209 I 0.01696 I I0.00007 0.00052 0.01760 nt1-Peak - Summer
Secondary 0.0299 1 0.15287 I 0.01696 I lo.00007 0.00052 0.01760 Primary 0.0299 1 0.15209 I 0.01696 I lo.00007 0.00052 0.01760 Qn-Peak - Winter
Secondary 0.0299 1 0.15287 I 0.01696 I lo.00007 000052 0.01760 Primary 0.0299 1 0.15209 I 0.01696 I I0.00007 0.00052 0.01760 ~m~P!i!i!k • Winlfi:
Secondary 0.0299 1 0.15287 I 0.01696 I io.00007 0.00052 0.01760 Primary 0.0299 1 0.15209 I 0.01696 I lo.00007 0.00052 0.01760 Qff•P!i!i!!s•:tiln!fi:
Secondary 0.0299 1 0.15287 I 0.01696 I lo.00007 0.00052 0.01760 Primarv 0.0299 1 0.15209 I 0.01696 I lo.00007 0.00052 0.01760 TOU Grandfathe ring Time Periods
6237 1-E
61914-E
Sheet6
T
RS R uoc
A Total
C
11.45 18.32
34.35 85.87
11.45 18.32
34.35 85.87
0.00001 0.21794 I
0.00001 0.21716 I
0.00001 0.21794 I
0.00001 0.21716 I
0.00001 0.21794 I
0.00001 0.21716 I
0.00001 0.21794 I
0.00001 0.21716 I
0.00001 0.21794 I
0.00001 0.21716 I
0.00001 0.21794 I
0.00001 0.21716 I
All time periods listed are applicable to local time. The definition of time will be based upon the date service is rendered.
Summer - June 1 - October 31 Winter - November 1 - Mal£ 31 On-Peak 11 a.m. - 6 p.m. Weekda ys 5 p.m. - 8 p.m. Weekdays Sem i-Peak 6 a.m. - 11 a.m. Weekdays 6 a.m. - 5 p.m. Weekdays 6 p.m. - 10 p.m. Weekdays 8 p.m. - 10 p.m. Weekdays
Off-Peak 10 p.m. - 6 a.m. Weekdays 10 p.m. - 6 a.m. Weekdays Plus Weekends & Holidays Plus Weekends & Holidays
6C7 Issued by Submitted See 3o, 2024
Advice Ltr. No. 4507 -E Dan Skopec Effective Oct 1, 2024 Senior Vice President
Decision No. 0 .24-07-013 Regulatory Affairs Resolution No. 2025 Nonresidential Alterations Reach Code Study 65
2025/07/07
9.4.5 City of Palo Alto Utilities
RESIDENTIAL MASTER-METERED A TIAL ELECTRIC
SERVICE
UTILITY RA TE SCHEDULE E-2
A. APPLICABILITY:
This Rate Schedule applie to the following Cu tomers receiving Electric Service from the City of Palo Alto tilitie :
1. on-residential Customers receiving on-Demand metered Electric Service; and
2. Customer with Account at Master-Metered multi-family facilities receiving on- Demand metered Electric Service.
B. TERRITORY:
This rate schedule applies everywhere the City of Palo Alto provides Electric Service.
C. :NBUNDLED RATES:
Per kilowatt-hour (kWh) Commodity Distribution Public Benefits Total Summer Period $ 0.14926 0.09735 $ 0.00549 $ 0.25210
Winter Period 0.09242 0.06623 0.00549 0.164 14
Customer Charge ($/month) 5.60
D. SPECIAL OTES:
1. Calculation of Cost Components
The actual bill amount is calculated ba ed on the applicable rate in Section C above and adjusted for any applicable discounts, surcharges and/or taxes. On a Customer's bill tatement, the bill amount may be broken down into appropriate component a calculated under Section C.
2. Sea onal Rate Change
CITY OF P
The Summer Period is effective May 1 to October 31 and the Winter Period is effective from ovember 1 to April 30. When the billing period includes use in both the ummer and the Winter Periods, the u age will be prorated ba ed on the nun1ber of day in each seasonal period, and the charges based on the applicable rates therein. For further discussion of bill calculation and proration, refer to Rule and Regulation 11.
TILIT IES
Issued by the City Council
Q
CITYOF
Supersedes Sheet No E-2-1
dated 7-1-2023
PALO ALTO
UTILITIES Sheet o E-2-1
Effective 7-1-2024
2025 Nonresidential Alterations Reach Code Study 66
2025/07/07
APP LI ABILITY :
ERVICE
UTILITY RA TE CHEDULE E-4
This Rate chedule applie to Demand metered econdary Electric ervice for Cu tomer with a maximum D mand below I 000 kilowatt . Thi Rat ch dule may includ ervice to ma ter- metered multi-family facilitie or other facilitie requiring Demand metered Service, a deten11ined by the City.
B. TERRITORY:
D.
Thi rate chedule applie everywhere the City of Palo Ito provide Electric erv1ce.
UNB IDLED RATE:
Rate per kilowatt (kW) and kilowatt-hour (kWh):
Commodity Di tribution
ummer Period
Demand Charge (per kW) 10.98 34.31
nergy harge (per kWh) 0.123 18 0.02520
Winter Period
Demand Charge (per kW) $ 2.57 21.16
Energy Charge (per kWh) 0.07949 0.02520
u tomer harge ( /month)
PECIAL NOTES:
1. Calculation of Co t Components
Public
Benefit
0.00549
0.00549
$ 45.29
0.153 7
$ 23.73
0.11018
I 13.73
The actual bill amount i calculated ba ed on the applicable rate in above and adju ted for any applicable di count urcharge and/or taxe . n a cu tomer' bill tatement, the bill amount may be broken down into appropriate component a calculated under ection C.
CITY OF PALO AL TO TILITIES
I ued by the City ouncil
PALO ALTO
Supersedes Sheet
dated 7-1-2023
Q
CITYO F
No E-4-1 UTILITIES Sheet 1o E-4-1
Effective 7-1-2024
2025 Nonresidential Alterations Reach Code Study 67
2025/07/07
MEDI 1 NO -RE ID TIAL ELECTRIC TIME OF E ERVICE
UTILITY RA TE SCHEDULE E-4 TOU
A. APPLICABILITY:
Thi volunta1y Rate chedule applie to Demand metered econdaiy lectric Service for Cu tomers with Demand behveen 500 and 1,000 kilowatt per month and who have u tained this level of usage for at least three consecutive months during the most recent 12 month period.
This Rate Schedule may include Service to Master-Metered multi-family facilitie or other facilities requiring Demand metered Service, as detennined by the City.
B. TERRITORY:
Thi rate chedule applie eve1ywhere the ity of Palo Alto provide Electric erv1ce.
C. UNBUNDLEDRATES:
Rates per kilowatt (kW) and kilowatt-hour (kWh):
ummer Period
Demand Charge (per kW)
Peak
Max Demand
Energy harge (per kWh)
Peak
Mid-Peak
Off-P ak
Winter Period
Demand Charge (per kW)
Peak
Max Demand
Energy Charge (per kWh)
Peak
Mid-Peak
Off-Peak
Customer Charge
( /month)
D. SPECIAL NOTES:
CITY OF PALO AL TO
Issued by the City Council
Supersedes Sheet No E-4- TOU-1
dated 7-1-2023
Commoditv
$ 9.72
1.29 $0.17038
0.14041
0.10556
1.30 1.30
$ 0.11976
0.09452
0.06525
Di tribution
$17.18
17.18 $ 0.02538
0.02538
0.02538
$ 10.73
10.73 $ 0.02500
0.02500
0.02500
O
CITYOF
PALO ALTO
UT ILIT IES
Public Benefit
$ 0.00549
0.00549
0.00549
$ 0.00549
0.00549
0.00549
Total
$ 26.90
18.47 $ 0.20125
0.17128
0.13643
$ 12.03
12.03 $ 0.15025
0.12501
0.09574
113.73
Sheet o E-4-TO -1
Effective 7-1-2024
2025 Nonresidential Alterations Reach Code Study 68
2025/07/07
RE IDENTIAL MA TER-METERED AND CO lMERCIAL GA
APP LI ABILITY:
This schedule applies to the following ustomer receiving Gas Service from the City of Palo Alto Utilitie :
1. ommercial Customer , ho use I than 250,000 thenn p r y ar at one ite·
2. Ma ter-metered residential ustomers in multi-family residential facilitie .
B. TERRITORY:
Thi chedule applie anywhere the City of Palo Ito provide Ga Service.
UNBUNDLED RA TE :
onthly ervice Charge: ..................................................................................................... $ 156.90 upply Charge :
l.
2. ommodity onthly Mark t Ba ed) ........................................ .
Cap and Trad Compliance Charg .......................................... .
3. Transpo1tation Charge ................................................................ .
4. arbon Offi et barge ................................................................. .
Di tribution Charge: ..................................................................... ............................ .
D. SPECIAL OTES:
1. Calculation of Cost Components
PerThenu
0.10-$4.00
0.00-$0.25
0.00-$0.25
0.00-$0.10
l.0809
The a tual bill amount i calculated ba ed on the applicable rate in ection above and adju ted for any applicable di counts, urcharge an or Taxe . On a Cu tom r' bill tat m nt, th bill amount may be brok n down iJ1tO appropriat compon nt a calculated under ection
The ommodity Charge i ba ed on the monthly natural ga Bidweek Price Index for delivery at PG&E itygate, adju ted to a count for delivery lo e to the Cu tomer' Meter. The ommodity barge al o include adju tment to account for ouncil- approved program implemented to reduce the co t of Ga , including a municipal purcha e discount 1, and a maximum 0.15/per therm co t for capped price winter natural 1 Adopted via Re olution 9451, on eptember 15. 2014.
ITY OF PALO AL TO UTILITIE
I ued by the City ouncil
Supersedes Sheet No G-2-1
dated 11-1-2023 Q
CITYOF
PALO ALTO
UTI LITIE S
Effective 7-1-2024
heet o G-2-1
2025 Nonresidential Alterations Reach Code Study 69
2025/07/07
The ‘Commodity and Volumetric Rates’ are selected for the latest available month of December 2020.10
10 https://www.paloalto.gov/files/assets/public/v/29/utilities/business/business-rates/monthly-gas- volumetric-and-service-charges-commercial.pdf
•
CITY OF
I PALO ALTO
UTILITIES
10/1/2024 0.4450
9/1/2024 0.3411
8/1/2024 0.5179
7/1/2024 0.4197
6/1/2024 0.1918
5/1/2024 0.2142
4/1/2024 0.2388
3/1/2024 0.2956
2/1/2024 0.5967
1/1/2024 0.4805
12/1/2023 0.6901
11/1/2023 0.7383
10/1/2023 0.4065
9/1/2023 0.4928
8/1/2023 0.5263
7/1/2023 0.4486
6/1/2023 0.3627
5/1/2023 0.5197
4/1/2023 0.6634
3/1/2023 0.7706
2/1/2023 1.2588
1/ 1/2023 4.0000
12/1/2022 1.4153
11/1/2022 0.7310
City of Palo Alto
Utility Rate Schedule G-2 - Residentia l Maste r-Metered and Commercial Gas Service Monthly Gas Volumetr ic and Service Charges
$ per Therm
0.1182 0.2500 0.0700
0.1451 0.2500 0.0700
0.1451 0.2201 0.0700
0.1451 0.2206 0.0700
0.1638 0.2206 0.0700
0.1638 0.2206 0.0700
0.1638 0.2206 0.0700
0.1534 0.2104 0.0700
0.1534 0.2022 0.0700
0.1534 0.2022 0.0700
0.1309 0.1350 0.0700
0.1309 0.1350 0.0700
0.1309 0.1350 0.0700
0.1132 0.1350 0.0700
0.1132 0.1345 0.0700
0.1132 0.1344 0.0700
0.1033 0.1345 0.0700
0.1033 0.1345 0.0700
0.0768 0.1345 0.0700
0.0768 0.1345 0.0700
0.0768 0.1345 0.0700
0.0768 0.1584 0.0700
0.0768 0.1584 0.0700
0.0768 0.1584 0.0700
0.8832
0.8062
0.9531
0.8554
0.6462
0.6686
0.6932
0.7294
1.0223
0.9061
1.0260
1.0742
0.7424
0.8110
0.8440
0.7662
0.6705
0.8275
0.9447
1.0519
1.5401
4.3052
1.7205
1.0362
1.0809
1.0809
1.0809
1.0809
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.8941
0.7365
0.7365
0.7365
0.7365
0.7365
0.7365
0.7365
0.7365
Total Volumetric Charge
(e)+(f)
1.9641
1.8871
2.0340
1.9363
1.5403
1.5627
1.5873
1.6235
1.9164
1.8002
1.9201
1.9683
1.6365
1.7051
1.7381
1.6603
1.4070
1.5640
1.6812
1.7884
2.2766
5.0417
2.4570
1.7727
S per Month
156.90
156.90
156.90
156.90
129.78
129.78
129.78
129.78
129.78
129.78
129.78
129.78
129.78
i 129.78
129.78
129.78
f-
106.90
106.90
106.90
106.90
106.90
106.90
106.90
106.90
2025 Nonresidential Alterations Reach Code Study 70
2025/07/07
9.4.6 Sacramento Municipal Utilities District (Electric Only)
9.4.7 Fuel Escalation Rates
Utility rates are assumed to escalate over time, using assumptions from research conducted by Energy and Environmental Economics (E3). As stated by E3 in the TDV report, this latter assumption “does not presuppose specific new investments, changes in load and gas throughput, or other measures associated with complying with California’s climate policy goals” (i.e., business-as-usual is assumed).
Table 33 below demonstrates the escalation rates used for nonresidential buildings.
II. Firm Service Rates
A. OlDlDtl'rinl & ludu lrinl Tiloe -of-Dny Rnte
CITS -0: C&I SecondaQ O 20 kW
~OD - ummt-1· ea,on (October • May)
~·srem lnfr nsrru<"lllrt- fb':td Chari:e par mo,1th per merer ~fosimum Dem•nd Cb•re• $ per mom/1/y max kW
Elf'<'fl'id~· Us Ajf' lrnref'
Pe•k SlkWI,
Off-Penk SlkWI,
Off-Peak Saver SlkW11
nmmer easou (June • September)
S~·stem Infrnstrncture-Fixed Chargt per monrh per merer '.\fo1:imum De-mand Chn1·s;it S per montlily max kW
Ele-enki~ • Usai:e Cbriri:e
Peok SlkWI,
Off-Peak SlkWI,
CITS -I: C&I Secondary 21-299 kW
:\"on- umme-r ea,on (October• May)
ysrtm lnfrasrrutturt flx ed Cbari:e per mo,irh per merer ire lufr . ,i; 11·11 r1ur e Ch!l1·a• pe,· J 2 months ma:r kW or contract capacfr:,1 [lf'('f.-iC'i(), " l.isaie b::irae
Peak 5/kWI,
Off-Peak SlkWI,
Off-Peak Sa.-er SlkW11
mnmt."r e-asoo (June • September)
ys1err1 Infr:1s1ruNure fil':l d Ch:u·ee per momlt per merer Sile lufr a <tj l1·11C'turt Charge pe,· I 2 months max kW or contract capacfry Summer Ptak Demand Chril'ge S per momlrl)' Peak max k-W Eltctl'id~ - Usag,t b:irgt
Peak SlkWI,
Off-Peak S/kW11
Commercial & Industrial Time-of-Day
Rate Schedule CI-TOD1
EfftNh ·r as of Effe<"rin as of
Jauuan · 1, 2023 Jauua1·v 1. 2024
S35.15 $36.65
S0.000 S0.713
S0.1440 $0.1446
S0.1364 $0.1335
S0.1323 $0.12 6
S35.15 $36,65
S0.000 S0.713
S0.2554 $0.2718
S0.1349 $0.1359
Sl58 .30 S231.60
S .568 $ .106
S0.1230 $0.1283
S0.1158 $0.11 0
S0.1030 S0.09 I
SISS.30 SBI.60
S .568 $ .106
S3.468 $ .3 1
S0.1983 $0.2056
S0.1119 $0.1129
Efft<"tfre-a'§. of
~Ia,· 1, 2024
$3 .65
$0, 33
so. 1485
S0.13 I
S0.1311
$3 .65
S0.733
$0.2 92
so 1396
$237.95
s .302
S0.1319
$0,1202
S0.0998
S237.95
$ .302
s .498
S0.2113
S0.1160
Effe-C'tfrt as of Efft<'ti\'f' as of
Januai ·v I. 2025 Ma,· I, 2025
$39.20 $40.30
S1.505 Sl.5~6
$0.1491 S0.1532
$0. 1341 S0.13
$0.1261 S0.129
$39.20 $40.30
$1.505 Sl.546
$0.2968 S0.3049
$0.1410 S0.1448
S31 .30 5326.05
S6.806 $6.993
$0.13 4 S0.1412
$0.1214 S0.1248
$0,0932 S0.0958
$31 .30 S326.05
S6.806 $6.993
S .525 s 32
$0,2192 S0.2252
$0,1171 S0.1203
Co111111ercial rates beyond 2025 are ejfectii-e as sho..-11 in Section VIII. Tra11sitio11 Schedule. 2025 Nonresidential Alterations Reach Code Study 71
2025/07/07
Table 33. Real Utility Rate Escalation Rate Assumptions Year
Statewide Electric
Nonresidential
Average Rate
(%/year, real)
Statewide Natural Gas
Nonresidential Core
Rate
(%/year, real)
2024 0.7% 7.7%
2025 0.5% 5.5%
2026 0.7% 5.6%
2027 0.2% 5.6%
2028 0.6% 5.7%
2029 0.7% 5.7%
2030 0.6% 5.8%
2031 0.6% 3.3%
2032 0.6% 3.6%
2033 0.6% 3.4%
2034 0.6% 3.4%
2035 0.6% 3.2%
2036 0.6% 3.2%
2037 0.6% 3.1%
2038 0.6% 2.9%
2039 0.6% 3.2%
2040 0.6% 2.9%
2041 0.6% 3.5%
2042 0.6% 3.4%
2043 0.6% 3.4%
2044 0.6% 3.4%
2045 0.6% 3.5%
2046 0.6% 2.0%
2047 0.6% 1.8%
2048 0.6% 2.1%
2049 0.6% 1.7%
2050 0.6% 2.1%
2051 0.6% 2.8%
2052 0.6% 2.8%
2053 0.6% 2.8%
Source: Energy & Environmental Economics, 2019, Reach Code Team
2025 Nonresidential Alterations Reach Code Study 72
2025/07/07
9.5 Prototype Characteristics
Table 34. Non-res Roof U-Value by CZ for three vintages (Wood Framed and Other Roof)
1980 vintage 1990 vintage 2000 vintage
Assembly
U-value
Assembly
U-value
Assembly
U-value
CZ1 0.076 0.056 0.051
CZ2 0.085 0.056 0.051
CZ3 0.085 0.056 0.051
CZ4 0.086 0.056 0.051
CZ5 0.085 0.056 0.051
CZ6 0.093 0.077 0.075
CZ7 0.093 0.077 0.075
CZ8 0.093 0.077 0.075
CZ9 0.092 0.076 0.075
CZ10 0.089 0.074 0.051
CZ11 0.086 0.056 0.051
CZ12 0.086 0.056 0.051
CZ13 0.086 0.056 0.051
CZ14 0.085 0.056 0.051
CZ15 0.088 0.056 0.051
CZ16 0.08 0.056 0.051
2025 Nonresidential Alterations Reach Code Study 73
2025/07/07
Table 35 Non-res Exterior Wall U-Value by CZ for three vintages 1980 vintage 1990 vintage 2000 vintage
Medium
Retail
Small
Office
Assembly
U-value
Assembly
U-value
CZ1 0.277 0.333 0.182 0.216
CZ2 0.329 0.382 0.189 0.216
CZ3 0.331 0.384 0.189 0.223
CZ4 0.339 0.392 0.189 0.223
CZ5 0.329 0.382 0.189 0.223
CZ6 0.402 0.451 0.189 0.223
CZ7 0.381 0.431 0.189 0.223
CZ8 0.399 0.448 0.189 0.223
CZ9 0.368 0.419 0.189 0.223
CZ10 0.358 0.409 0.189 0.216
CZ11 0.338 0.39 0.182 0.216
CZ12 0.335 0.387 0.182 0.216
CZ13 0.34 0.393 0.182 0.216
CZ14 0.325 0.378 0.182 0.216
CZ15 0.389 0.438 0.182 0.216
CZ16 0.294 0.349 0.182 0.216
2025 Nonresidential Alterations Reach Code Study 74
2025/07/07
Table 36. Non-res Window U-Value, SHGC and VT for all vintages Window Assembly U-Value Window SHGC Window VT
1980
vintage
1990
vintage
2000
vintage
1980
vintage
1990
vintage
2000
vintage
1980
vintage
1990
vintage
2000
vintage
CZ1 1.144 0.689 0.468 0.568 0.549 0.427 0.36 0.383 0.4
CZ2 1.179 1.143 0.468 0.73 0.668 0.358 0.36 0.383 0.4
CZ3 1.209 1.168 0.763 0.735 0.672 0.407 0.36 0.383 0.4
CZ4 1.209 1.168 0.763 0.735 0.672 0.407 0.36 0.383 0.4
CZ5 1.209 1.168 0.763 0.735 0.672 0.407 0.36 0.383 0.4
CZ6 1.209 1.168 0.763 0.733 0.671 0.387 0.36 0.383 0.4
CZ7 1.209 1.168 0.763 0.733 0.671 0.387 0.36 0.383 0.4
CZ8 1.209 1.168 0.763 0.733 0.671 0.387 0.36 0.383 0.4
CZ9 1.209 1.168 0.763 0.733 0.671 0.387 0.36 0.383 0.4
CZ10 1.179 1.143 0.468 0.73 0.668 0.358 0.36 0.383 0.4
CZ11 1.144 0.689 0.468 0.561 0.544 0.358 0.36 0.383 0.4 CZ12 1.144 0.689 0.468 0.561 0.544 0.358 0.36 0.383 0.4 CZ13 1.144 0.689 0.468 0.561 0.544 0.358 0.36 0.383 0.4 CZ14 1.144 0.689 0.468 0.561 0.544 0.358 0.36 0.383 0.4 CZ15 1.144 0.689 0.468 0.561 0.544 0.358 0.36 0.383 0.4 CZ16 1.144 0.689 0.468 0.568 0.549 0.427 0.36 0.383 0.4 Table 37. Equipment Turnover Assumptions
Measure
Category
1980 Vintage 1990 Vintage 2000 Vintage
1980 1990 2000 2016 1980 1990 2000 2016 1980 1990 2000 2016 HVACSHW 71% 9% 14% 5% 0% 84% 12% 4% 0% 0% 97% 3%
Roofs 74% 8% 13% 5% 0% 86% 10% 4% 0% 0% 98% 2%
Windows 80% 7% 10% 4% 0% 89% 8% 3% 0% 0% 98% 2%
Walls 92% 3% 4% 1% 0% 96% 3% 1% 0% 0% 99% 1%
Process 63% 12% 19% 7% 0% 79% 15% 6% 0% 0% 96% 4%
Ltg 45% 15% 28% 12% 0% 67% 24% 9% 0% 0% 94% 6%
ExtLtg 71% 9% 14% 5% 0% 84% 12% 4% 0% 0% 97% 3%
The equipment turnover assumptions in Table 37 are based on SB350 Appendix B2-NR Vintage Data and represent best estimates for equipment replacements, not direct data.
Existing equipment efficiencies were estimated by weighting the code minimum requirements by the replacement rates. For example, the AFUE was assumed to be 63% for 1980, 78% for 1990 and 2000, and 80% for 2016. Using the equipment turnover assumptions above, this calculates to a weighted average of 67.5% AFUE for the 1980s vintage, and 78.1% for the 1990s and 2000s vintages.
2025 Nonresidential Alterations Reach Code Study 75
2025/07/07
9.6 Occupancy Schedules and Building Types
The Reach Code Team explored how the results could apply to other building types with similar occupancy schedules. Figure 10 shows that Small Office shares similar occupancy schedules with Large Office, Library, and Financial Institutions, while Medium Retail aligns closely with Grocery. School, however, exhibits slightly different occupancy patterns, so the results may not be directly applicable to this building type. Other building types with significantly different occupancy schedules are not considered to be applicable.
Figure 10. Occupancies in 141.0-E-1 Schedules
9.7 Interview Guide
The Reach Code Team used the following guide for the market actor interviews. This guide asks similar questions for all market actors. For some questions, the wording is different for designers (“Des”) and contractors (“Cont”) — who work directly on projects, compared to distributors (Dist) and manufacturer reps (MFR) — who sell equipment, but still have an understanding of project challenges and opportunities through their involvement with the construction process and communication with their clients.
Introduction
Thank you for taking the time to speak with us today. As a reminder, we are conducting this interview on behalf of the California investor-owned utilities to understand HVAC retrofits.
Specifically, we are interested in your experience with the retrofit of rooftop units. This would include replacing gas-fired rooftop units (gas packs) with packaged heat pumps, and your experience with other efficiency measures. All answers will be kept anonymous. 0 0. 2
0. 4
0. 6
0. 8
1 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 O ccu p an cy F r act io n
Hour of Da y
Me d iu m Re t a il
Gro c e ry
Sm a ll Offic e
La rge Offic e
L ib ra ry
Fina nc ia l Ins
Sc hool
2025 Nonresidential Alterations Reach Code Study 76
2025/07/07
Do we have your permission to record this interview? This is solely for note-taking purposes. a. Yes [RECORD CONTACT INFORMATION; SETUP INTERVIEW
TIME; EMAIL INTERVIEW TOPICS]
b. No [DISCUSS CONCERNS; ANSWER QUESTIONS; ATTEMPT TO CONVERT TO “YES”]
1. (All) What is your role withing your organization?
2. (Cont/Des) What types of commercial projects have you worked on in the past year? a. (Dist/MFR) For what types of commercial projects have you sold HVAC products in the past 5 years?
3. (All) What area of California do you typically work in?
4. (Cont) Do you replace gas packs with heat pumps? How many replacements have you performed in the past year?
a. (Dist/MFR) Do you sell equipment for replacing gas packs with heat pumps? i. If yes, how often is this equipment sold? (Always, almost always, sometimes, rarely, never)
Research Topic A: Replacing gas packs with heat pumps
1. (Des/Cont) In general, have you faced challenges replacing gas packs with heat pumps? Y/N
a. If yes, what are those challenges?
2. (Dist/MFR) In general, have your customers faced challenges replacing gas packs with heat pumps? Y/N
a. If yes, what are those challenges?
If they don’t mention them, then probe:
3. (All)Are there any physical concerns or space constraints? Y/N a. If yes, what are those challenges? (don’t ask, but if they don’t volunteer, then probe)
Probe for: unit footprint, curb height, equipment weight b. How often is a curb adapter required? What are the cost implications?
4. (Cont/Des) Are there electrical concerns? Y/N (Interviewer can skip this section for Dist/MFR as these questions are geared for designers and contractors) a. If yes, what are those concerns?
b. What type of electrical upgrades are typical when replacing gas packs with heat pumps?
c. Is the additional capacity of electric resistance defrost enough to require electrical upgrades?
5. (All) Are there building heating capacity issues with replacing gas packs with heat pumps? Y/N
a. If yes, what are the issues? (don’t ask, but if they don’t volunteer, then probe) Probe for: meeting the building’s space heating loads.
2025 Nonresidential Alterations Reach Code Study 77
2025/07/07
b. Under what conditions is electric resistance for defrost necessary? i. (If they don’t specify, then ask): Is this unique to specific locations or climates?
c. (Dist/MFR) Have you ever not been able to keep up with heating setpoint temperature because electric resistance for defrost was not installed? Research Topic B: Non-preempted ECMs for gas-for-gas HVAC unit replacement
We are looking to identify additional efficiency measures that could be installed as part of a gas-for-gas retrofit.
1. The first technology we’re considering is an ERV/HRV. a. (All) Are you familiar with the technology? Y/N
i. (Cont/Des): If Yes, how many times have you installed/specified them in the past year?
1.(Dist/MFR): How many have you sold in the last year?
ii. (All) Where in California are ERV/HRV most effective/appropriate? iii. (All) Are there areas of California where ERV/HRV would NOT be effective? b. (Des/Cont) Would you design/install an ERV/HRV separate from the rooftop unit or integrate them?
c. (Dist/MFR) [If integrated]: By percentage, how many ERV/HRV units have you sold with gas pack replacements? (Provide the multiple-choice ranges only if they are unwilling to estimate a value.)
i. <25%
ii. Between 25% and 75%
iii. More than 75%
iv. Not sure
d. (Dist/MFR) [If separate]: By percentage, how many ERV/HRV units have you sold with gas pack replacements? (Provide the multiple-choice ranges only if they are unwilling to estimate a value.)
v. <25%
vi. Between 25% and 75%
vii. More than 75%
viii. Not sure
2. Demand control ventilation (DCV) is another measure we are considering. a. Are you familiar with the technology?
b. Is this a good measure for retrofits?
c. (If time) Are there areas of California where this would NOT be effective?
3. We are also considering RTU fan ECM motor with staged controls. a. Are you familiar with the technology?
b. Is this a good measure for retrofits?
2025 Nonresidential Alterations Reach Code Study 78
2025/07/07
c. (If time) Are there areas of California where this would NOT be effective?
4. We are also considering options for making a programmable thermostat more effective, such as by having it programmed by the installer.
a. (Des/Cont) When you install/specify thermostats, how often do you set a schedule or setpoints?
b. How do you determine a schedule for a thermostat when you program one? c. How often are you called back to reset a schedule for a programmable thermostat? d. (All) Which type of thermostat would be less likely to be overridden by the customer so that energy savings are actually achieved? Programmable where installer programs it according to customer preferences? Smart? Something else?
5. Do you have recommendations for any other efficiency measures to consider? ( if they don’t volunteer, probe for DCV, RTU fan ECM motor with staged controls, DOAS)
6. (If time) Another measure we are considering is a dedicated outdoor air system (DOAS). a. Are you familiar with the technology? Y/N
i. If Yes, how often have you installed/specified them in the past year? b. What is your opinion on DOAS systems?
i. Are there areas of California where DOAS saves more energy? Are there areas of California where DOAS would NOT be effective?
7. Are you able to provide some cost estimates for the measures discussed today as a follow - up via email?
Section C: Closing
Great! Thank you so much for your time. Those are all the questions we have for you today. For taking the time to speak to me today we will be emailing you a $150 e-gift card which you should receive in the next ten business days as a thank you. Before we finish, do you have any questions for me, or anything else you would like to add?
2025 Nonresidential Alterations Reach Code Study 79
2025/07/07
Get In Touch
The adoption of reach codes can differentiate
jurisdictions as efficiency leaders and help accelerate the adoption of new equipment, technologies, code
compliance, and energy savings strategies.
As part of the Statewide Codes & Standards
Program, the Reach Codes Subprogram is a
resource available to any local jurisdiction located
throughout the state of California.
Our experts develop robust toolkits as well as provide
specific technical assistance to local jurisdictions
(cities and counties) considering adopting energy
reach codes. These include cost-effectiveness
research and analysis, model ordinance language
and other code development and implementation
tools, and specific technical assistance throughout
the code adoption process.
If you are interested in finding out more about local
energy reach codes, the Reach Codes Team stands
ready to assist jurisdictions at any stage of a reach
code project.
Visit
LocalEnergyCodes.com to
access our resources and
sign up for newsletters
Contact
[email protected]
for no-charge assistance from
expert Reach Code advisors
Explore
The Cost-Effectiveness
Explorer is a free resource to
help California local
governments and
stakeholders develop energy
policies for buildings.
Follow
us on Linkedin
Revision: 1.0
Last modified: 2025/07/07