Clark Public Utilities

Conservation Potential Assessment

October 22, 2015

Prepared by:

570 Kirkland Way, Suite 100 Kirkland, Washington 98033

A registered professional engineering corporation with offices in Kirkland, WA and Portland, OR

Telephone: (425) 889-2700 Facsimile: (425) 889-2725

October 22, 2015

Mr. Larry Blaufus Clark Public Utilities P.O. Box 8900 Vancouver, Washington 98668

SUBJECT: 2015 Conservation Potential Assessment – Final Report

Dear Larry:

Please find attached the Final Report summarizing the 2015 Clark Public Utilities Conservation Potential Assessment (CPA). This report covers the time period from 2016 through 2035 (20 years). Significant changes have occurred since the last CPA due to updated measure and appliance standard information. The overall energy efficiency potential is significant, but due to changes in market conditions and measures since the Sixth Power Plan, it is somewhat lower than the previous assessment.

We would like to acknowledge and thank you and your staff for the excellent support in developing and providing the baseline data for this project.

Best Regards,

Gary Saleba President

570 Kirkland Way, Suite 100 Kirkland, Washington 98033

Telephone: 425 889-2700 Facsimile: 425 889-2725

A registered professional engineering corporation with offices in Kirkland, WA and Portland, OR

Contents

EXECUTIVE SUMMARY ...... 1 BACKGROUND ...... 1 RESULTS ...... 2 TARGETS AND ACHIEVEMENT ...... 5 CONCLUSION ...... 6 INTRODUCTION ...... 7 OBJECTIVES ...... 7 ELECTRIC UTILITY RESOURCE PLAN REQUIREMENTS ...... 7 ENERGY INDEPENDENCE ACT ...... 8 STUDY UNCERTAINTIES ...... 8 REPORT ORGANIZATION ...... 9 CPA METHODOLOGY ...... 11 BASIC MODELING METHODOLOGY ...... 11 TYPES OF POTENTIAL ...... 12 RECENT CONSERVATION ACHIEVEMENT ...... 17 CURRENT CONSERVATION PROGRAMS ...... 17 SUMMARY ...... 21 CUSTOMER CHARACTERISTICS DATA ...... 22 RESULTS – ENERGY SAVINGS AND COSTS ...... 29 TECHNICAL ACHIEVABLE CONSERVATION POTENTIAL ...... 29 ECONOMIC ACHIEVABLE CONSERVATION POTENTIAL ...... 30 SECTOR SUMMARY ...... 30 COST ...... 34 SCENARIOS ...... 37 BASE CASE...... 37 SCENARIOS ...... 37 SAVINGS SHAPE RESULTS ...... 41 PEAK DEMAND SAVINGS...... 43 SUMMARY ...... 46 METHODOLOGY AND COMPLIANCE WITH STATE MANDATES ...... 46 CONSERVATION TARGETS ...... 47 SUMMARY ...... 47 REFERENCES ...... 48 APPENDIX I – ACRONYMS ...... 50 APPENDIX II – GLOSSARY ...... 51 APPENDIX III – DOCUMENTING CONSERVATION TARGETS ...... 53 APPENDIX IV – AVOIDED COST AND RISK EXPOSURE ...... 57 APPENDIX V – CPU LOAD AND COINCIDENCE FACTORS ...... 66 APPENDIX VI – MEASURE LIST ...... 68 APPENDIX VII – ENERGY EFFICIENCY POTENTIAL BY END-USE ...... 76 APPENDIX VIII – MEASURE DETAIL ...... 78

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List of Tables

Table ES-1 Cost-Effective Potential - Base Case (aMW) ...... 2 Table ES-2 Comparison of 2013 CPA and 2015 CPA Cost-Effective Potential (aMW) ...... 4 Table 1 Residential Building Characteristics ...... 22 Table 2 Commercial Building Square Footage by Segment ...... 23 Table 3 Industrial Sector Load by Segment ...... 24 Table 4 Process Shares – Indoor Agriculture Segment ...... 26 Table 5 Cost-Effective Achievable Potential (aMW) ...... 30 Table 6 Distribution Efficiency – 20-Year Cost-Effective Achievable Potential ...... 34 Table 7 Cost for Economic Achievable Conservation Potential ...... 35 Table 8 Cost Scenarios for Base Case Economic Achievable Conservation Potential ...... 36 Table 9 Cost per MWh Savings (First Year) for Base Case Economic Achievable Potential ...... 36 Table 10 Cost-Effective Achievable Potential – Low Scenario (aMW) ...... 38 Table 11 Cost-Effective Achievable Potential – Accelerated Base Scenario (aMW) ...... 38 Table 12 Cost-Effective Achievable Potential – Scenario Comparison (aMW) ...... 39 Table 13 Cumulative Peak Demand Savings with Associated Energy Savings and Costs ...... 45

List of Figures

Figure ES-1 Annual Base Case Energy Efficiency Potential Estimates ...... 3 Figure ES-2 Comparison of Conservation Targets to Achievements ...... 6 Figure 1 Conservation Potential Assessment Process ...... 11 Figure 2 Types of Energy Efficiency Potential ...... 12 Figure 3 20-Year Market Price Forecast (Mid-Columbia) ...... 15 Figure 4 CPU Recent Conservation History by Sector ...... 17 Figure 5 Residential Program Achievement by End-Use CY 2013 - 2014 ...... 19 Figure 6 Commercial and Industrial Program Achievement by End-Use CY 2013 - 2014 ...... 21 Figure 7 Indoor Agriculture Electricity End-Use Distribution ...... 25 Figure 8 20-Year End System Load Forecast ...... 28 Figure 9 20-Year Technical-Achievable Potential Supply Curve...... 29 Figure 10 Annual Achievable Potential by Sector ...... 30 Figure 11 Annual Residential Potential by End-Use ...... 31 Figure 12 Annual Commercial Potential by End-Use ...... 32 Figure 13 Annual Industrial Potential by End-Use ...... 33 Figure 14 Annual Distribution System Efficiency Potential ...... 34 Figure 15 CPU Conservation Scenarios – Annual Potential (aMW) ...... 39 Figure 16 CPU Monthly Energy Efficiency Savings, HLH ...... 41 Figure 17 CPU Monthly Energy Efficiency Savings, LLH ...... 42 Figure 18 CPU Monthly Energy Efficiency Savings, HLH, Cumulative ...... 42 Figure 19 Annual Peak Demand Savings, Cumulative (MW)...... 43 Figure 20 Monthly Peak Demand Savings, Cumulative (MW) ...... 44

Clark Public Utilities—Conservation Potential Assessment ii

Executive Summary

This report describes the methodology and results of the Clark Public Utilities (CPU) 2015 Conservation Potential Assessment (CPA). This assessment provides estimates of energy and peak demand savings by sector for the period 2016 to 2035. The assessment considered a wide range of conservation resources that are reliable, available, and cost-effective within the 20- year time horizon.

Background

CPU provides electricity service to more than 192,500 customers located in Clark County, Washington. CPU’s service territory covers 667 square miles and includes 6,600 miles of transmission and distribution lines.

Washington’s Energy Independence Act (EIA), effective January 1, 2010, requires that utilities with more than 25,000 customers (known as qualifying utilities) pursue all cost-effective conservation resources and meet conservation targets set using a utility-specific conservation potential assessment methodology. The EIA sets forth specific requirements for setting, pursuing and reporting on conservation targets. The methodology used in this assessment complies with RCW 19.285.040 and WAC 194-37-070 Section 5 parts (a) through (o) and is consistent with the methodology used by the Northwest Power and Conservation Council (Council) in developing the Sixth Power Plan. Thus, this Conservation Potential Assessment will support CPU’s compliance with EIA requirements.

This assessment builds on CPU’s CPA conducted in 2010-2011, and updated in 2013, by utilizing the same methodology and similar models. However, significant changes in the marketplace have taken place since 2010, many of which were documented in the Council’s Sixth Power Plan Mid-Term Assessment1. As a result, substantial revisions to the planning assumptions were required for this CPA. The primary model updates included the following:

 New Avoided Cost – recent forecast of power market prices  Updated Financial Parameters – including discount rate, transmission and distribution credits, risk credits and other inputs  Updated Customer Characteristics Data • New commercial data from the 2014 Commercial Building Stock Assessment (CBSA) • Updated kWh consumption and Energy Use Intensity (EUI) data  Measure Updates

1 Sixth Power Plan Mid-Term Assessment Report. Northwest Power and Conservation Council, March 13, 2013.

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• Added new measures from the Regional Technical Forum (RTF) and the Northwest Power and Conservation Council (Council) • Removed measures that have expired or are now covered by Federal standards or state energy codes  Thirty five new or revised standards have been adopted since the 6th Plan  A new edition of the Washington State Energy Code (WSEC) became effective in 2013 • Revised/updated measure data for existing measures • Updated measure saturation data from the Council  Accounting for Recent Achievements • Internal programs • NEEA programs

The first step of this assessment was to carefully define and update the planning assumptions using the new data. The Base Case conditions were defined as the most likely market conditions over the planning horizon, and the conservation potential was estimated based on these assumptions. Additional scenarios were also developed to test a range of conditions.

Results

Table ES-1 shows the high level results of this assessment. The economically achievable potential by sector in 2, 5, 10 and 20-year increments is included. The total 20-year cost- effective conservation potential is 68.42 aMW. The focus of the EIA requirement is on the 10- year potential, 39.14 aMW, and the 2-year potential, 7.74 aMW.

Table ES-1 Cost-Effective Potential2 - Base Case (aMW) 2 Year* 5 Year 10 Year 20 Year Residential 4.41 11.62 22.38 41.95 Commercial 2.00 5.43 10.39 16.49 Industrial 1.23 2.93 5.01 6.25 Distribution Efficiency 0.10 0.44 1.37 3.73 TOTAL 7.74 20.41 39.14 68.42 *2016 and 2017

These estimates include energy efficiency achieved through CPU’s own utility programs, and also through CPU’s share of the Northwest Energy Efficiency Alliance (NEEA) accomplishments.

2 Cost-effective potential identified in this report refers to potential that has passed the Total Resource Cost test and has had the regional applicability factors applied (e.g., 85% for retrofit measures). Cost-effective potential is both cost-effective AND achievable.

Clark Public Utilities—Conservation Potential Assessment 2

These estimates include energy efficiency that could be achieved through CPU’s own utility programs and also through CPU’s share of the Northwest Energy Efficiency Alliance (NEEA) accomplishments. In addition, it is likely that some code changes will account for part of the potential, especially in the later years.

The 20-year energy efficiency potential is shown on an annual basis in Figure ES-1. This assessment shows potential starting around 3.8 aMW in 2016 and ramping up to 4.3 aMW per year in 2020. Potential is accelerated in the early years of the study and then is gradually ramped down through the remaining years of the planning period.

This potential is shown on an annual basis in Figure ES-1.

Figure ES-1 Annual Base Case Energy Efficiency Potential Estimates 5.0

4.5

4.0

3.5

3.0

2.5 aMW 2.0

1.5

1.0

0.5

-

Residential Commercial Industrial Distribution Efficiency

The majority of the potential is in the residential sector. The distribution of residential sector conservation among measure end uses is similar to CPU’s 2013 residential conservation profile. The notable areas for achievement include:

 Water Heating – Including heat pump water heaters and showerheads  Consumer electronics – including desktop computers and advanced power strips  LED lighting in existing homes  Heat pump and ductless heat pump upgrades, conversions and supplements

Significant conservation is available in CPU’s commercial sector, though the 2015 results in this sector are considerably lower compared with commercial sector potential estimated in the 2013 CPA. In addition, the distribution of end-use savings for the commercial sector is

Clark Public Utilities—Conservation Potential Assessment 3

somewhat different than in previous CPAs. Some of this difference can be attributed to the significant commercial measure updates that have been made for the 2015 CPA. Specifically, twelve new measure bundles were added to the commercial sector, some previous measures expired or are now covered by state energy codes or federal equipment standards, and the majority of the remaining measures were updated with the latest data from the RTF and Council. Notable areas for commercial sector achievement include:

 HVAC controls – including advanced rooftop controller and energy management measures  Lighting – including lighting power density improvements and low power fluorescent lamps  Commercial ductless heat pumps  Refrigeration – including grocery refrigeration measures and water cooler controls

Table ES-2 shows the comparison of the Base Case results in the 2013 and current 2015 assessments. Both 10-year and 20-year cost-effective achievable potential are shown.

Table ES-2 Comparison of 2013 CPA and 2015 CPA Cost-Effective Potential (aMW) 10-year 20-year 2013* 2015* % Change 2013* 2015* % Change Residential 36.0 22.4 -38% 74.2 42.0 -43.4% Commercial 14.4 10.4 -28% 25.9 16.5 -36.3% Industrial 1.4 5.0 257% 2.9 6.3 117.2% Distribution Efficiency 1.8 1.4 -22% 3.6 3.7 2.8% TOTAL 53.6 39.1 -27% 106.5 68.4 -35.8% *Note that the 2013 columns refer to the CPA completed in 2013 for the time period of 2014 through 2033. The 2015 assessment is for the timeframe 2016 through 2035.

Substantial changes were made to residential, commercial, industrial and agriculture sectors, which significantly affected overall conservation potential. The residential sector was significantly affected due in large part to higher baselines. Baseline adjustments are two-fold: energy efficiency programs have been effective in increasing the saturation of the measures, and new codes and standards have changed measure definitions. Essentially, homes are becoming more efficient due to programs, market transformation efforts, and code and standard updates. Some of the key differences by measure or end use are listed below:

 Residential Weatherization Measures – The RTF released a new set of single-family weatherization measures for existing homes after extensive review of savings estimates for these measure sets. As a result, savings for these new measures are 60 percent lower, on average. Some residential weatherization measures for new homes were removed due to new building codes.  Residential Appliances – A number of new standards have recently been passed which affect residential appliances, including dishwashers, refrigerators, freezers and clothes

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washers. More standards will become effective in the first few years of the conservation planning period. These changes have resulted in new appliance measures with lower incremental savings over current market conditions, as compared to market conditions assumed in the 2013 CPA (higher baselines).  Consumer Electronics – Residential consumer electronics potential increased due to the addition of cost-effective advanced power strip measures.  Commercial Heat Pump Water Heaters – Heat pump water heaters are a new measure for the commercial sector. These measures constitute a significant amount of cost- effective commercial conservation.  Commercial HVAC Controls – New commercial energy management measures added notable savings in the commercial sector.  Energy Independence and Security Act of 2007 (EISA) – This code change significantly impacted both residential and commercial lighting potential. Standards affecting incandescent and CFL lighting have been phased in since 2012 and CFL measures were eliminated in 2014. New measures have been added for LED lighting and solid state lighting.  Industrial End-Use Savings – The distribution of end-use consumption in the industrial sector was significantly revised due to Council review.

Targets and Achievement

Figure ES-2 compares historic achievement with CPU’s targets. The 2016 and 2017 targets are based on the Base Case scenario presented in this report. The figure shows that CPU has consistently met its energy efficiency targets, and that the potential estimates presented in this report are achievable through CPU’s utility conservation programs and the utility’s share of NEEA savings. ES-2 shows projected achievement for 2015.

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Figure ES-2 Comparison of Conservation Targets to Achievements

9.0 8.0 7.0 6.0

5.0

aMW 4.0 3.0 2.0 1.0 0.0 2010 2011 2012 2013 2014 2015 2016 2017

Achievement Estimated Potential Target

Conclusion

This report summarizes the CPA conducted for Clark Public Utilities for the 2016 to 2035 planning period. Based on the results of the Base Case scenario, the total 10-year cost effective potential is 39.1 aMW and the 2-year potential is 7.7 aMW. The results of this assessment are lower than the previous assessment due to changes in market conditions, code and standard changes, recent conservation achievements, and revised savings values for RTF and Council measures.

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Introduction

Objectives

The objective of this report is to describe the results of the Clark Public Utilities’ (CPU) 2015 Conservation Potential Assessment (CPA). This assessment provides estimates of energy savings by sector for the period 2016 to 2035, with the primary focus on 2016 to 2025 (10 years). This analysis has been conducted in a manner consistent with requirements set forth in 19.285 RCW (EIA) and 194-37 WAC (EIA implementation) and is part of CPU’s compliance documentation. The results and guidance presented in this report will also assist CPU in strategic planning for its conservation programs in the near future. Finally, the resulting conservation supply curves can be used in CPU’s integrated resource plan (IRP).

The conservation measures used in this analysis are based on the most recent set of measures approved by the Regional Technical Forum (RTF) and are representative of the measures that will be used in the Council’s Seventh Power Plan. The assessment considered a wide range of conservation resources that are reliable, available, and cost-effective within the 20-year planning period.

Electric Utility Resource Plan Requirements

CPU provides electricity service to more than 192,500 customers located in Clark County, Washington. CPU’s service territory covers 667 square miles and includes 6,600 miles of transmission and distribution lines. CPU serves its loads with a variety of resources, including demand side resources. In October 2011, CPU began purchasing power from the Bonneville Power Administration (BPA) as a Slice/Block customer under a power contract signed in December 2008. As a Slice/Block customer, CPU purchases an approximate 2.2% share of the real-time capability of the Federal Based System (FBS) and monthly flat blocks of energy. CPU expects average annual supply from the Slice/Block contract to be between 294 to 310 aMW, with peak capability of 508 MW. Under good water conditions, it is estimated that BPA resources could provide up to 70% of CPU’s power requirements through the end of the contract term in 2028. As a Slice/Block customer CPU relies on scheduled output from the FBS as well as market transactions to follow load.

CPU owns and operates the River Road Generating Plant; a 248 MW natural gas-fired power plant. The utility estimates that this resource will provide approximately 225 aMW of average annual generation to serve loads for the foreseeable future. Output from the River Road plant meets approximately 37% of CPU’s current annual average load requirements. In 2009, CPU signed a contract to purchase the entire output of the Combine Hills II wind project for a 20- year term, which began in January 2010. Average annual supply from this resource is approximately 18 aMW. CPU is under contract to purchase 18% of the production capability of the Packwood Project. This hydroelectric project is owned and operated by Energy Northwest

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and CPU’s share provides approximately 1.1 aMW of average annual energy to serve utility loads.

According to Chapter 19.280 RCW, utilities with at least 25,000 customers are required to develop integrated resource plans (IRPs) by September 2008 and biennially thereafter. The legislation mandates that these resource plans include assessments of commercially available conservation and energy efficiency measures. This CPA is designed to assist in meeting these requirements for conservation analyses. The results of this CPA may be used in the next IRP due to the state by September 2016. More background information is provided below.

Energy Independence Act

Chapter 19.285 RCW, the Energy Independence Act, requires that, “each qualifying utility pursue all available conservation that is cost-effective, reliable and feasible.” The timeline for requirements of the Energy Independence Act are detailed below:

 By January 1, 2010 – Identify achievable cost-effective conservation potential through 2019 using methodologies consistent with the Pacific Northwest Power and Conservation Council’s (Council) latest power planning document.  Beginning January 2010, each utility shall establish a biennial acquisition target for cost- effective conservation that is no lower than the utility’s pro rata share for the two-year period of the cost effective conservation potential for the subsequent ten years.  By June 2012, and 2014, each utility shall submit an annual conservation report to the department (the department of commerce or its successor). The report shall document the utility’s progress in meeting the targets established in RCW 19.285.040.  Beginning on January 1, 2014, cost-effective conservation achieved by a qualifying utility in excess of its biennial acquisition target may be used to help meet the immediately subsequent two biennial acquisition targets, such that no more than twenty percent of any biennial target may be met with excess conservation savings.

This report summarizes the preliminary results of a comprehensive CPA conducted following the steps provided for a Utility Analysis. A checklist of how this analysis meets EIA requirements is included in Appendix III (p. 54).

Study Uncertainties

The savings estimates presented in this study are subject to the uncertainties associated with the input data. This study utilized the best available data at the time of its development; however, the results of future studies will change as the planning environment evolves. Specific areas of uncertainty include the following:

 Customer characteristic data – Residential and commercial building data and appliance saturations are in many cases based on regional studies and surveys. There are

Clark Public Utilities—Conservation Potential Assessment 8

uncertainties related to the extent that CPU’s service area is similar to that of the region, or that the regional survey data represents the population.  Measure data – In particular, savings and cost estimates (when comparing to current market conditions), as prepared by the Council and RTF, will vary across the region. In some cases, measure applicability or other attributes have been estimated by the Council or the RTF based on professional judgment or limited market research.  Market Price Forecasts – Market prices (and forecasts) are continually changing. The market price forecasts for electricity and natural gas utilized in this analysis represent a snapshot in time. Given a different snapshot in time, the results of the analysis would vary. However, risk credits are included in the analysis to mitigate the market price risk over the study period.  Utility System Assumptions – Credits have been included in this analysis to account for the avoided costs of bulk transmission and distribution system expansion and local distribution system expansion. Though potential transmission and distribution system cost savings are dependent on local conditions, the Council considers these credits to be representative estimates of these avoided costs.  Discount Rate – The Council develops a real discount rate for each power plan based on the relative share of the cost of conservation and the cost of capital for the various program sponsors. The Council has estimated these figures using the most current available information. This study reflects the current borrowing market although changes in borrowing rates will likely vary over the study period.  Forecasted Load and Customer Growth – The CPA bases the 20-year potential estimates on forecasted loads and customer growth. Each of these forecasts includes a level of uncertainty.  Load Shape Data – The Council provides conservation load shapes for evaluating the value of time-differentiated energy savings. In practice, load shapes will vary by utility based on weather, customer types, and other factors. This assessment uses utility- specific load and coincidence factors to estimate peak demand savings over the planning period, based on shaped energy savings. Since the load shapes are representative of the region, and are not specific to CPU, peak demand savings presented in this report may vary from actual peak demand savings.  Frozen Efficiency – Consistent with the Council’s methodology, the measure baseline efficiency levels and end-using devices do not change over the planning period. In addition, it is assumed that once an energy efficiency measure is installed, it will remain in place over the remainder of the study period.

Due to these uncertainties and the changing environment, under the EIA, qualifying utilities must update their CPAs every two years to reflect the best available information.

Report Organization

The main report is organized with the following main sections:

 Methodology – CPA methodology along with some of the overarching assumptions

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 Recent Conservation Achievement – CPU’s recent achievements and current energy efficiency programs  Customer Characteristics – Housing and commercial building data for updating the baseline conditions  Results – Energy Savings and Costs – Primary base case results  Scenario Results – Results of all scenarios  Savings Shape and Demand Savings Results – Base Case potential results by month and by sector  Summary  Appendices

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CPA Methodology

This study is a comprehensive assessment of the energy efficiency potential in CPU’s service area. The methodology complies with RCW 19.285.040 and WAC 194-37-070 Section 5 parts (a) through (o) and is consistent with the methodology used by the Northwest Power and Conservation Council (Council) in developing the Sixth Power Plan. This section provides a broad overview of the methodology used to develop CPU’s conservation potential target. Specific assumptions and details of methodology as it pertains to compliance with the EIA compliance are provided in Appendix III (p. 54) of this report.

Basic Modeling Methodology

The basic methodology used for this assessment is illustrated in Figure 1. A key factor is the kilowatt hours saved annually from the installation of an individual energy efficiency measure. The savings from each measure is multiplied by the total number of measures that could be installed over the life of the program. Savings from each individual measure are then aggregated to produce the total potential.

Figure 1 Conservation Potential Assessment Process

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Types of Potential

Three types of potential are used in this study: technical, achievable, and economic potential. Technical potential is the theoretical maximum efficiency in the service territory if cost and achievability barriers are excluded. There are physical barriers, market conditions, and other consumer acceptance constraints that reduce the total potential savings of an energy efficient measure. When these factors are applied, the remaining potential is called the achievable potential. Economic potential is a subset of the technical-achievable potential that has been screened for cost effectiveness through a benefit-cost test. Figure 2 illustrates the four types of potential followed by more detailed explanations.

Figure 2 Types of Energy Efficiency Potential3

Not Technically Technical Potential Feasible

Not Technically Market & Achievable Potential Feasible Adoption Barriers

Not Technically Market & Not Cost-Effective Economic Potential Feasible Adoption Barriers

Program Design, Not Technically Market & Budget, Staffing, Program Not Cost-Effective Feasible Adoption Barriers & Time Potential Constraints Technical – Technical potential is the amount of energy efficiency potential that is available, regardless of cost or other technological or market constraints, such as customer willingness to adopt measures. It represents the theoretical maximum amount of energy efficiency absent these constraints in a utility’s service territory.

Estimating the technical potential begins with determining a value for the energy efficiency measure savings. Then, the number of “applicable units” must be estimated. “Applicable units” refers to the number of units that could technically be installed in a service territory.

3 Reproduced from U.S. Environmental Protection Agency. Guide to Resource Planning with Energy Efficiency. Figure 2-1, November 2007.

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This includes accounting for units that may already be in place. The “applicability” value is highly dependent on the measure and the housing stock. For example, a heat pump measure may only be applicable to single family homes with electric space heating equipment. A “saturation” factor accounts for measures that have already been completed.

In addition, technical potential considers the interaction and stacking effects of measures. For example, if a home installs insulation and a high-efficiency heat pump, the total savings in the home is less than if each measure were installed individually (interaction). In addition, the measure-by-measure savings depend on which measure is installed first (stacking).

Total technical potential is often significantly more than the amount of economic and achievable potential. The difference between technical potential and economic potential is due to the number of measures in the technical potential that are not cost-effective and the applicability or total amount of savings of those non-cost effective measures.

Achievable – Achievable potential is the amount of potential that can be achieved with a given set of conditions. Achievable potential takes into account many of the realistic barriers to adopting energy efficiency measures. These barriers include market availability of technology, non-measure costs, and physical limitations of ramping up a program over time. The level of achievable potential can increase or decrease depending on the given incentive level of the measure. The Council uses achievability rates equal to 85 for retrofit measures and 65 % for lost opportunity measures over the 20-year study period. This CPA follows the Council’s methodology, including the achievability rate assumptions. Note that the achievability factors are applied to the technical potential before the economic screening.

Economic – Economic potential is the amount of potential that passes an economic benefit-cost test. In Washington State, the total resource cost test (TRC) is used to determine economic potential (per EIA requirements). This means that the present value of the benefits exceeds the present value of the costs over the lifetime of the measure. TRC costs include the incremental costs and benefits of the measure regardless of who pays a cost or receives the benefit. Costs and benefits include the following: capital cost, O&M cost over the life of the measure, disposal costs, program administration costs, environmental benefits, distribution and transmission benefits, energy savings benefits, economic effects, and non-energy savings benefits. Non- energy costs and benefits can be difficult to enumerate, yet non-energy costs are quantified where feasible and realistic. Examples of non-quantifiable benefits might include: added comfort and reduced road noise from better insulation, or increased real estate value from new windows. A quantifiable non-energy benefit might include reduced detergent costs or reduced water and sewer charges.

For this potential assessment, the Council’s ProCost models are used to determine cost- effectiveness for each energy efficiency measure. The ProCost model values measure energy savings by time of day using conservation load shapes (by end-use) and segmented energy prices. The version of ProCost used in the 2015 CPA evaluates measure savings on a monthly basis and by four segments. The four segments differentiate savings values across heavy load hour, shoulder, and light load hour periods in each month.

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Program – Program potential is the amount of potential that can be achieved through utility administered programs. The program achievable potential excludes savings estimates that are achieved through future code changes and market transformation. The program potential is not the emphasis of this assessment, but understanding the sources of achievement is an important reporting requirement.

Energy Efficiency Measure Data

The characterization of efficiency measures includes measure savings (kWh), demand savings (kW), measure costs ($), and measure life (years). Other features, such as measure savings shape, operation and maintenance costs, and non-energy benefits are also important components of the measures. The Council’s Seventh Power Plan is scheduled for release at the end of 2015, and the vast majority of the conservation analysis has been completed and made available. Due to the timing of this CPA, the primary sources for conservation measure data are the Council’s Seventh Plan supply curve workbooks, which include the most recent information.

The measure data include adjustments from raw savings data for several factors. The effects of space-heating interaction, for example, are included for all lighting and appliance measures, where appropriate. For example, if an electrically-heated house is retrofitted with efficient lighting, the heat that was originally provided by the inefficient lighting will have to be made up by the electric heating system. These interaction factors are included in measure savings data to produce net energy savings.

Other financial-related data needed for defining measure costs and benefits include: current and forecasted loads, growth rates, discount rate, avoided costs, line losses, and deferred capacity-expansion benefits.

A list of measures by end-use is included in this CPA is included in Appendix VI (P. 69).

Avoided Cost

The avoided cost of energy is represented as a dollar value per MWh of conservation. Avoided costs are used to value energy savings benefits when conducting cost effectiveness tests and are generally included in the numerator in a benefit-cost test. These energy benefits are often based on the cost of a generating resource, a forecast of market prices, or the avoided resource identified in the integrated resource planning process. Figure 3 shows the price forecast used as the primary avoided cost component for the planning period. The price forecast is shown for heavy load hours (HLH), light load hours (LLH), and average load hours (ALH).

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Figure 3 20-Year Market Price Forecast (Mid-Columbia)

$100 $90 $80 $70

$60 HLH $50

$/MWh $40 ALH $30 LLH $20 $10 $0

The EIA requires that utilities “…set avoided costs equal to a forecast of market prices.” As discussed in Appendix IV (p. 58), CPU may be resource deficit on an average annual basis as early as 2021, under a high load growth scenario. In addition, the utility already experiences annual peak load deficits. Market purchases may be used to serve future load growth. Therefore, the market price forecast shown in Figure 3 is appropriate for modeling the value of avoided energy.

The EIA also requires that deferred capacity expansion benefits for transmission and distribution systems be included in the cost-effectiveness analysis. To account for the value of deferred bulk transmission and local distribution system expansion, a local system distribution credit value of $31/kW-yr and a bulk transmission and distribution system credit of $23.14/kw- yr were applied to peak savings from conservation measures. The local distribution system credit is taken from the Council’s Seventh Plan supporting documents. The bulk transmission credit used in this assessment is based on Council’s bulk transmission credit assumption calculated for the Seventh Power Plan adjusted for CPU’s transmission coincident factor. Specifically the Seventh Plan bulk transmission system credit is $26/kw-yr, based on updated cost estimates for deferred upgrades and expansion of the regional transmission system. However, CPU’s peak load is not fully coincident with the regional peak. Thus, peak demand savings from CPU’s conservation achievement should be adjusted when evaluating the deferral of transmission system expansion investments. Over the past three years, CPU’s system peak has been 89% coincident with the regional peak, represented by the Bonneville Power Administration’s (BPA) system peak. Accordingly, CPU’s bulk transmission and distribution credit for this assessment is adjusted to 89% of the regional $26/kw-yr. A $23.14/kw-yr transmission credit is used in the cost-effectiveness analysis for this assessment.

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Risk credits of $22.72/MWh and $32.46/MWh were included in the avoided cost for retrofit and lost opportunity measures, respectively, to account for the reduced power supply cost risk associated with energy efficiency measures.

A sensitivity analysis around the value of the risk mitigation credit is included in this study. Additional information regarding the avoided cost forecast and risk mitigation credit values is included in Appendix IV (p. 58).

Finally, a 10% benefit was added to the avoided cost as required by the Pacific Northwest Electric Power Planning and Conservation Act.

Discount Rate

The Council develops real discount rate assumptions for each of its Power Plans. The most recent real discount rate assumption developed by the Council is 4% based recent conservation program data collected from 2008 to 2012. The 4% discount rate was developed to model conservation potential for the Seventh Power Plan. The discount rate is used to convert future cost and benefit streams into present values. The present values are then used to compare net benefits across measures that realize costs and benefits at different times and over different useful lives (years).

The discount rate is developed from two sets of assumptions. The first set of assumptions describes the relative shares of the cost of conservation distributed to various sponsors. Conservation is funded by the Bonneville Power Administration (BPA), utilities, and customers. The second set of assumptions looks at the financing parameters for each of these entities to establish the after-tax average cost of capital for each group. These figures are then weighted, based on each group’s assumed share of project cost to arrive at a composite discount rate. The Council’s 4% discount rate is used in this analysis.

Building Characteristic Data

Building characteristics, baseline measure saturation data, and appliance saturation influence CPU’s total conservation potential. For this analysis, the characterization of CPU’s baseline was determined using data provided by county records. Details of data sources and assumptions are described for each sector later in the report.

This assessment primarily sourced baseline measure saturation data from the Council’s Seventh Plan measure workbooks. The Council’s data was developed from NEEA’s Building Stock Assessments, studies, market research and other sources, and the Council has updated baselines for regional conservation achievement in preparation for the release of the Seventh Power Plan in January 2016. Historic conservation achievement data are often used to update measure saturation levels when current market data is unavailable. EES adjusted measure baselines, using CPU’s conservation achievement history, for those measures with baselines that have not been updated since the 2011 Residential Building Stock Assessment. CPU’s historic achievement is discussed in detail in the next section.

Clark Public Utilities—Conservation Potential Assessment 16

Recent Conservation Achievement

CPU has pursued conservation and energy efficiency resources since 1980. The utility currently offers several rebate and incentive programs for both residential and non-residential applications. CPU also provides information to customers in the form of energy-use tracking software and professional energy audits to inform customers of the types of energy efficiency applications that may be most suitable for their home or facility.

CPU has consistently conserved energy through its commercial and residential programs and has conserved significant energy through its industrial programs. In 2014, 2.68 aMW of energy was saved through industrial programs; this was the highest annual industrial achievement in at least five years.

Figure 4 shows the distribution of conservation among the utility’s customer sectors and also shows conservation achieved through Northwest Energy Efficiency Alliance (NEEA) efforts over the past five years. CPU obtains a share of NEEA savings through two avenues: 1) CPU’s share of regional load, and 2) CPU’s contributions to BPA programs.

Figure 4 CPU Recent Conservation History by Sector

9.0 8.0 7.0 6.0

5.0

aMW 4.0 3.0 2.0 1.0 0.0 2010 2011 2012 2013 2014

Residential Commercial Industrial NEEA

Current Conservation Programs

CPU offers a wide range of conservation programs to its customers. These programs include several residential loan programs, rebates, energy audits, and commercial projects. The current programs offered by CPU are detailed below followed by recent achievements for these programs.

Clark Public Utilities—Conservation Potential Assessment 17

Residential

 Recycling Programs – CPU offers $30 bill credits for recycling qualifying refrigerators and freezers. In addition CPU offers CFL light bulb replacements for light bulbs recycled at CPU’s offices.

 Energy Star® Rebates – CPU offers a number of rebates for energy star appliances. These include $25 for refrigerators and $50 for clothes washers.

 Weatherization Loans – This loan program provides five and seven year low interest loans (3.5 % minimum), up to $15,000 for air sealing, duct sealing, attic insulation, wall insulation, floor insulation and window replacement. Loan processing fees apply.

 Weatherization Rebates – Rebates of up to $400 are available for floor, attic, or wall insulation improvements, and up to $500 for energy efficient window replacements. CPU also offers up to $250 rebates for PTCS duct sealing and 50 % (up to $100) of the cost of air- sealing envelope.

 Weatherization Assistance – Using state and public utility funds, CPU offers low-income weatherization grants. These programs offer insulation and minor weatherization-related repairs to Clark County families with income up to 125 % of the federal poverty level. Participants are responsible for 10 % of the project costs and participant commitment is capped at $500. This program is open to customers with electrically-heated homes.

 Heat Pump Loans – The utility offers financing up to $20,000 for installation of air source or ductless heat pumps. Eligible customers include those with electrically heated homes in existing construction.

 Heat Pump Rebates – Rebates of up to $750 are available for energy efficient air-source heat pumps and ductless heat pumps.

 Heat Pump Water Heater Rebates – The utility offers $300 for Tier 1 qualifying heat pump water heaters and $500 for Tier 2 qualifying heat pump water heaters.

 Solar Water Heater Rebates – CPU is offering a $500 rebate on the installation of a qualifying solar water heater. In addition to the rebate, qualified customers may finance up to $10,000 of the cost of a solar water heating system.

 Solar Pool Heating Systems – CPU offers $500 rebates, with financing of up to $10,000 for solar pool heaters.

 On-Site Visit – Energy auditors are available over the phone and on-site for home energy efficiency improvements. Energy auditors analyze energy use, provide tips on winterization, guide customers through home improvement upgrades related to weatherization, provide written information on conservation products, programs, and practices, and they are available to speak to groups and organizations regarding home energy efficiency improvements.

 Photovoltaic Systems – CPU offers financing up to $30,000 for installation of solar cells or photovoltaic.

Clark Public Utilities—Conservation Potential Assessment 18

 Energy Star Homes – Homes which meet Energy Star Homes requirements for Washington are eligible for a $1,500 rebate, paid to the Energy Star builder.

Figure 5 summarizes the recent savings achievement for the above utility-managed programs. These savings do not include end-use savings from CPU’s share of NEEA savings.

Figure 5 Residential Program Achievement by End-Use CY 2013 - 2014

Appliances 3% HVAC 22%

Energy Star Homes 2%

Envelope 8% Lighting 57% Water Heating 1%

Appliance Recycling 7% Commercial and Industrial

 Commercial Lighting Improvement Program (CLIP) – CPU offers rebates to commercial and industrial customers for approved LED lighting projects. A lighting audit is conducted to determine the upgrade opportunities and rebate amounts.

 EnergySmart Grocer – This program offers grocery customers, restaurants and other businesses with commercial refrigeration no-cost energy audits and information regarding energy efficient technology, operations, and management. CPU offers rebates to offset the cost of energy efficient upgrades and retrofit projects, potentially covering up to 100 % of equipment expenses.

 EnergySmart Industrial – This program offers technical resources and incentives for industrial facility efficiency improvements. Current incentives may cover up to 50 % of project cost for retrofit projects and 70 % for new construction projects (capped at varying per kilowatt rates for verified savings).

Clark Public Utilities—Conservation Potential Assessment 19

 Commercial Building Energy Audits – Key account managers provide walk-throughs to identify opportunities for energy efficiency. This service is free and provides information to business owners regarding energy efficiency and bill reductions.

 Green Motor Rewind – Motors between 15 and 5,000 horsepower can be rewound to improve their efficiency. CPU offers incentives of at least $1 per horsepower for qualifying rewinds.

 Compressed Air Audits – CPU offers financial assistance to manufacturing customers to assist with the completion of compressed air audits. Professional energy specialists identify energy efficiency gains that lead to improved air supply, enhanced maintenance cycles, and noise reductions.

 Heat Pump Equipment Conversion and Upgrade in Commercial Buildings – An incentive program is available for qualifying air source heat pump equipment conversions and upgrades in buildings with electric resistance heat and which meet additional program specifications.

 Small Commercial Ductless Heat Pump (DHP) – CPU’s commercial DHP program offers reimbursement of $250 per ton of installed outdoor capacity for eligible DHP units and installations.

 Web-Enabled Programmable Thermostats (WEPT) – CPU offers incentives to help offset the costs of new and existing WEPTs installed in commercial buildings.

 Multifamily Weatherization – CPU offers a range of rebates for weatherization improvements in electrically-heated multifamily housing. The utility currently offers incentives for attic, wall, and floor insulation, as well as improvements to windows and patio doors.

 Energy Management Software – CPU offers two software packages for energy tracking and analysis in commercial and industrial applications. Both E-Manager and Energy Expert are web-based programs that provide electricity consumption data to indicate areas where the facility may benefit most from energy efficiency improvements. E- Manager provides hourly consumption data and is designed for manufacturing and production facilities where electricity costs are due primarily to equipment load. Energy Expert provides building energy modeling solutions, based on daily energy consumption.

 Custom Projects – The custom project program provides incentives to commercial and industrial customers who install energy efficiency measures. The utility currently offers incentives for up to 50 % of project cost for retrofit projects and 70% for new construction projects (capped at varying per kilowatt rates for verified savings).

Figure 6 summarizes the recent savings achievement by end-use for the above utility-managed programs. These savings do not include end-use savings from CPU’s share of NEEA savings.

Clark Public Utilities—Conservation Potential Assessment 20

Figure 6 Commercial and Industrial Program Achievement by End-Use CY 2013 - 2014

Roof Top Units / Ind Lighting Ductless Heat Pumps Controls 2.3% 0.0% 0.2% Web Enabled Thermostats 0.3% Energy Smart Grocer Com Custom 6.5% Projects 15.7% Green Motors 0.0%

Com Lighting 21.2% Ind Custom Projects 47.4%

Track & Tune 3.0% HPEM 3.2% Insulation Appliances 0.0% 0.0%

Summary

CPU plans to continue offering incentives for energy efficiency investments. The results of this study will assist CPU program managers decide in strategic planning for energy efficiency program offerings, incentive levels, and program review.

Clark Public Utilities—Conservation Potential Assessment 21

Customer Characteristics Data

CPU serves approximately 192,500 electricity customers in Clark County, with a total service territory population of approximately 474,600. A key component of an energy efficiency assessment is to understand the characteristics of these customers – primarily the building and end-use characteristics. Characteristics for each customer class are described below.

Residential

For the residential sector, the key characteristics include house type distribution, space-heating fuel type, and water heating fuel. Table 1 shows relevant residential data for single family, multi-family and manufactured homes in CPU’s service territory. The data for new and existing homes were provided by CPU and are based on Clark County data collected for the Northwest Energy Efficiency Alliance (NEEA) 2011 Residential Building Stock Assessment (RBSA). These data provide an estimate of the current residential characteristics in Clark County and are utilized as the baseline in this study. The Regional % columns show 2011 RBSA data weighted by the regional distribution of home types (new and existing).4 These data have been provided for reference.

Table 1 Residential Building Characteristics Heating Cooling Residential Zone Zone Solar Zone Households Total Population 1 1 2 174,379 474,599

Housing Stock Existing New Homes Regional % Existing New Regional %

House Type Foundation Type

Single Family 76% 98% 72% Crawlspace 73% 79% 58%

Multi-Family 21% 2% 18% Full Basement 17% 11% 26% Manufactured Homes 3% 0% 10% Slab on Grade 10% 10% 16%

Housing Vintage Water Heating

Pre-1980 35% N/A 61% Electric 51% 11% 65%

1980 - 1993 19% N/A 18% Natural Gas 49% 89% 32%

Post 1993 46% N/A 20% Heat Fuel Type Appliance Saturation

Natural Gas Homes 38% 89% 24% Refrigerator 130% 100% 123%

Electric Homes 46% 11% 55% Freezer 47% 0% 43%

Other Fuel Homes 16% 0% 21% Clothes Washer 99% 99% 89%

Electric Heat System Type Electric Dryer 97% 97% 88%

Forced Air Furnace 17% 11% 11% Dishwasher 94% 94% 85%

Heat Pump 27% 54% 17% Electric Oven 89% 82% 79%

Zonal (Baseboard) 44% 28% 70% Room AC 14% 0% 13%

Electric Other 13% 7% 1% Central AC 40% 40% 38%

4 Single-family and multi-family reference data are specific to Washington State and regional (WA, OR, ID and western MT) data were used to describe manufactured homes characteristics.

Clark Public Utilities—Conservation Potential Assessment 22

Commercial

Building square footage is the key parameter in determining conservation potential for the commercial sector, as many commercial measures are based on savings as a function of building square footage (kWh/sf). CPU provided 2014 commercial square footage and energy consumption (kWh) for each of the 18 building types shown in Table 2. The 2014 commercial sector square footage totaled 80.27 million square feet. Overall, the commercial square footage estimates used in the 2015 CPA are 1.11 million square feet higher compared with the 2013 CPA.

Regional energy use intensity values (EUI) are often used to derive commercial sector square footage by segment if only energy consumption data is available. To establish square-footage using EUIs, annual kWh consumption by segment is divided by regional EUI data to produce square foot data. These figures are then benchmarked and adjusted to county building database figures. Since CPU provided square footage and energy consumption data, the EUI values shown in Table 2 were calculated based on the utility-provided data. Regional EUI values were used to benchmark building square footage for this assessment.

Regional growth rates by building type were adjusted to match expected growth for the commercial rate class. The growth rates presented in Table 2 are net of commercial building demolition assumptions for CPU’s service territory. Demolition rates are based on Council assumptions of -0.4% annually (varies by building segment).

Table 2 Commercial Building Square Footage by Segment Segment Area (Square Feet)* EUI (kWh/sf)* Net Growth Rate Large Office 3,241,665 18.0 1.2% Medium Office 5,185,203 16.5 1.2% Small Office 11,603,638 7.7 1.2% Big Box Retail 2,797,306 33.1 0.3% Small Box Retail 6,113,163 6.9 0.3% High End Retail 1,256,987 16.3 0.3% Anchor 371,051 16.2 0.3% K-12 Schools 13,151,257 10.0 0.6% University 1,128,771 14.0 0.7% Warehouse 11,048,787 5.0 1.1% Supermarket 1,660,922 39.2 -0.5% Mini Mart 602,761 51.7 0.5% Restaurant 1,588,369 45.0 0.7% Lodging 4,412,155 18.0 0.3% Hospital 2,065,984 32.0 0.8% Other Health Facilities 3,613,602 20.0 1.5% Assembly Hall 5,625,044 14.0 1.0%

Clark Public Utilities—Conservation Potential Assessment 23

Table 2 Commercial Building Square Footage by Segment Other 4,807,882 14.0 -0.4% Total 80,274,549 0.8% *Square footage and EUI data provided by CPU.

Industrial

The methodology for estimating industrial potential is different than approaches used for the residential and commercial sectors primarily because industrial energy efficiency opportunities are based on the distribution of electricity use among processes at industrial facilities. Industrial potential for this assessment was estimated based on the Council’s “top-down” methodology that utilizes annual consumption by industrial segment and then disaggregates total electricity usage by process shares to create an end-use profile for each segment. Estimated measure savings are applied to each sector’s process shares. Table 4 shows an example of an end-use profile for one industrial segment.

CPU provided 2014 energy consumption for each of the 20 industrial segments shown in Table 3. The 2014 industrial load totaled 883,391 MWh. However, CPU expects to complete a project for an electric manufacturing customer in late 2015 or early 2016 which will save the customer an estimated 6 aMW (52,560 MWh). Since it is expected that electrical manufacturing load will be 6 aMW lower at the beginning of the 2015 CPA planning period, the estimated project savings have been removed from the MWh inputs for the electric manufacturing segment. The total adjusted load is 834,789. This figure is approximately 71,100 MWh lower compared with the 2013 CPA. Industrial sector consumption and growth rates by segment are shown in Table 3. Regional growth rates were revised based on current sector loads and estimated future growth.

Table 3 Industrial Sector Load by Segment Annual Growth Rate Annual Base Load - 2014 MWh (Regional Average ) Mechanical Pulp - 0.8% Kraft Pulp - 1.0% Paper 12,678 0.2% Foundries 6,364 0.6% Frozen Food 3,067 -0.3% Other Food 69,849 0.4% Sugar 0 -0.1% Lumber 10,344 -0.5% Panel 1,633 -0.3% Wood 15,525 0.6% Electric Fabrication 438,173 0.5% Silicon 2,692 -1.0% Metal Fabrication 43,739 1.0% Equipment 1,096 -1.9% Cold Storage - 2.1%

Clark Public Utilities—Conservation Potential Assessment 24

Table 3 Industrial Sector Load by Segment Annual Growth Rate Annual Base Load - 2014 MWh (Regional Average ) Fruit Storage - 2.2% Refinery - -0.9% Chemical 114,067 0.5% Miscellaneous Manufacturing 113,083 1.0% Indoor Agriculture 897 1.2% Total 834,798 0.6%

A new industrial segment was added for CPU’s 2015 CPA: indoor agriculture (marijuana grow operations). This segment is not part of the Council’s standard 19 industrial subsectors included in the Sixth Power Plan, so end-use electricity profiles were created based on industry research and other Council analyses. Specifically, the Council has conducted surveys of marijuana grow operations in order to begin modeling energy usage at these facilities.5 The Council’s research indicates that electricity use in marijuana grow operations is distributed as shown in Figure 7.

Figure 7 Indoor Agriculture Electricity End-Use Distribution

Vent & Space Heating Dehumid 5% 30%

AC 21%

CO2 Inject. 2% Water Handling 3%

Drying Lighting 1% 38% Table 4 shows the resulting end-use profile for indoor agriculture operations. Adjustments were made to measure applicability to account for the high probability of slow customer adoption of energy efficiency measures in this subsector. Slow adoption is expected since this is a new area for energy efficiency applications; and anecdotal evidence from the region

5 Northwest Power and Conservation Council. Impact of Cannabis Production in the Pacific Northwest on Regional Electricity Loads. September 9, 2014. Available online: http://www.nwcouncil.org/media/7130334/p7.pdf

Clark Public Utilities—Conservation Potential Assessment 25

suggest indoor agriculture business owners can be difficult to reach and may be reluctant to adopt some of the measures. Since non-medical marijuana grow operations are illegal at the federal level, CPU is not permitted to use BPA funds to pay for energy efficiency incentives for indoor agriculture customers. Table 4 Process Shares – Indoor Agriculture Segment Pumps 3% Drying and Curing 1% HVAC 51% Lighting 38% Other Process 7% All Electric 100% All Motors 44%

CPU estimated near term indoor agriculture growth based on current licensed square footage and square footage for pending licenses. This assessment projects 5% annual load growth in the indoor agriculture segment for the next five years, and that no growth will occur in this segment for the remaining years of the planning period. This translates to a 1.23% annual growth rate, as shown in Table 3.

Total estimated conservation potential for indoor agriculture facilities is 0.012 aMW over the study period. This translates to 9% savings from baseline consumption for the indoor agriculture segment.

Distribution Efficiency (DEI)

As discussed in CPU’s 2013 CPA, the utility has conducted a significant amount of research and completed numerous upgrades to their distribution system. CPU participated in a “Distribution System Efficiency and Voltage Optimization Scoping Study” in 2010 to determine the availability of distribution system efficiency upgrades and optimization. Based on the findings from that report, total energy savings of 1,600 MWh per year were estimated for the three substations tested (0.82% reduction).

For CPU’s 2013 CPA, distribution efficiency potential was estimated in two ways: 1) multiplying the individual substation savings (0.06 aMW) by the number of substations in CPU’s service territory (55), and 2) multiplying the estimated savings as a percent of load (0.82%) by the total 2012 CPU load of 515.7 aMW. The two approaches provided similar results and CPU staff selected the percent savings approach (this method estimated the highest potential).

For this analysis, EES developed an additional estimate of distribution system conservation potential using the Council’s Seventh Plan approach. The Seventh Plan estimates distribution potential as a fraction of end system sales or 0.12 to 4.4 kWh per MWh depending on measure. For reference, the Sixth Power Plan estimated DEI savings as 1.7 to 8.1 kWh per MWh of system sales. CPU provided a total system load forecast for 2015-2024. This forecast is consistent with the utility forecast submitted as part of CPU’s most recent annual North American Electric

Clark Public Utilities—Conservation Potential Assessment 26

Reliability Corporation (NERC) reliability report. The forecast was escalated through the end of the planning period (2035) using the average annual growth rate from 2016 to 2024 (0.16%). The forecast was then adjusted for line loss using CPU’s 2013 total system losses (3.6%). The results of CPU’s end system load forecast are shown in Figure 8, and distribution system conservation is discussed in detail in the next section.

Clark Public Utilities—Conservation Potential Assessment 27

Figure 8 20-Year End System Load Forecast

545

540

535

530 aMW

525

520

515

Clark Public Utilities—Conservation Potential Assessment 28

Results – Energy Savings and Costs

Technical Achievable Conservation Potential

Technical achievable potential is the amount of energy efficiency potential that is available regardless of cost. It represents the theoretical maximum amount of achievable energy efficiency savings.

Figure 9, below, shows a supply curve of 20-year, technically achievable potential. The supply curve is developed by plotting energy efficiency savings potential (aMW) against the levelized cost ($/MWh) of the savings. The technical potential shown in Figure 8 has not been screened for cost effectiveness. Costs are standardized (levelized), allowing for the comparison of measures with different lives. The supply curve facilitates comparison of demand-side resources to supply-side resources and is often used in conjunction with integrated resource plans (IRPs). Figure 9 shows that approximately 63 aMW of potential is available for less than $30/MWh and approximately 79 aMW is available for under $80/MWh. Total technical achievable potential for CPU is approximately 99 aMW over the 20-year study period.

Figure 9 20-Year Technical-Achievable Potential Supply Curve

110.0

100.0

90.0

80.0

aMW 70.0

60.0

50.0

40.0 <10 <20 <30 <40 <50 <60 <80 <90 <100 <110 <120 120+ Levelized $/MWH

Clark Public Utilities—Conservation Potential Assessment 29

Economic Achievable Conservation Potential

Economic potential is the amount of potential that passes the Total Resource Cost (TRC) test. This means that the present value of the benefits exceeds the present value of the measure costs over its lifetime.

Table 5 shows aMW of economically achievable potential by sector in 2, 5, 10 and 20-year increments. Annual potential estimates by sector are included in Appendix VII (p. 77). Compared with the technical and achievable potential, it shows that 68.42 aMW of the total 99.07 aMW is cost effective for CPU. The last section of this report discusses how these values could be used for setting targets.

Table 5 Cost-Effective Achievable Potential (aMW) 2 Year 5 Year 10 Year 20 Year Residential 4.41 11.62 22.38 41.95 Commercial 2.00 5.43 10.39 16.49 Industrial 1.23 2.93 5.01 6.25 Distribution Efficiency 0.10 0.44 1.37 3.73 TOTAL 7.74 20.41 39.14 68.42

Sector Summary

Figure 10 shows achievable potential by sector on an annual basis.

Figure 10 Annual Achievable Potential by Sector

5.0 4.5 4.0 3.5

3.0

2.5 aMW 2.0 1.5 1.0 0.5 -

Residential Commercial Industrial Distribution Efficiency

Clark Public Utilities—Conservation Potential Assessment 30

Over half of the potential, on an annual basis, is in the residential sector, followed by substantial savings potential in the commercial sector. The industrial sector potential is significant as well due largely to end-use savings distribution work by the RTF. Ramp rates from the Seventh Power Plan are used to establish reasonable annual conservation achievement levels. Achievement levels are affected by factors including timing and availability of measure installation (lost opportunity), program (technological) maturity, non-programmatic savings, and current utility staffing and funding.

Residential

Residential conservation potential is substantially lower compared with previous assessments. Savings were reduced for many measures due to baseline changes and savings recalibration and analysis from the RTF and Council. In particular, residential weatherization measure savings and heat pump water heater savings have been significantly reduced.

Figure 11 shows the distribution of annual residential potential across measure end uses for the first ten years of the planning period. Lighting measures account for a significant fraction of conservation potential in the residential sector. Residential lighting measures have been replaced due to lighting standards that took effect over the past two years. Whereas previous residential lighting measure sets included CFL measures, the new measure set is designed solely around LED lighting. Incremental savings for residential lighting measures are considerably higher compared with previous lighting measures. Consumer electronics is another area with significant conservation potential. Though savings have been reduced for some residential consumer electronics measures, overall savings for consumer electronics have increased, due to the addition of cost-effective advanced power strip measures.

Figure 11 Annual Residential Potential by End-Use

3.0

2.5 Cooling

2.0 Envelope New

Appliances

1.5 Consumer Electronics aMW Water Heat 1.0 Envelope Retro HP / DHP 0.5 Lighting

0.0 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

Clark Public Utilities—Conservation Potential Assessment 31

Commercial

Commercial lighting measures remain one of the largest contributors to commercial conservation potential, though savings have been significantly reduced since CPU’s previous CPA (Figure 12). HVAC control measures make up a substantial part of commercial conservation potential for this assessment period, due largely to new savings estimates for advanced rooftop controller measures.

Conservation potential for refrigeration measures remains strong although commercial refrigeration potential has been reduced somewhat compared to previous assessments. RTF changes to deemed refrigeration measures prompted numerous revisions and expirations. Packaged refrigeration measures were removed and grocery refrigeration bundle measures were revised. New measures for water cooler controls were added to refrigeration. Another notable area for this assessment is savings due to commercial ductless heat pump measures. This is a new measure bundle with notable cost-effective savings. As shown in Figure 12, the custom nature of commercial building energy efficiency improvements is reflected in the wide variety of end-uses and corresponding measures.

Figure 12 Annual Commercial Potential by End-Use

1.40 Compressed Air 1.20 Motors HP / DHP 1.00 Water Heat Street/Roadway Lighting 0.80 Chillers

Food Preparation aMW 0.60 Ventilation Envelope 0.40 Ext Lighting Refrigeration 0.20 HVAC Controls PC Network/Supply 0.00 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 Lighting

Industrial

Industrial conservation potential has been significantly impacted by end-use savings distribution work completed by the RTF. CPU has achieved notable savings from industrial conservation projects since the previous assessment which reduces available industrial potential over the planning period.

Clark Public Utilities—Conservation Potential Assessment 32

Over half of the industrial sector conservation potential is due to electronic manufacturing processes (Figure 13). This corresponds to the distribution of industrial sector load across the industry loads, since the electric fabrication segment is expected to account for approximately half of CPU’s industrial sector load in 2035.

Industrial lighting measures also account for a notable share of sector savings. Lighting measures are widely applicable across many of the industrial segments. Conservation potential for municipal wastewater treatment plants is included in Figure 13. Savings estimates for these measures are based on equipment upgrades and modifications to operations/processes and facilities. Adding end-use savings across the industry segments results in total industrial sector potential.

Figure 13 Annual Industrial Potential by End-Use

0.70 Refrigerated Storage 0.60 Water Supply & Wastewater Pumps 0.50 Process: Wood Mfg

0.40 Process: Paper Mfg

aMW Process: General 0.30 Process: Electronic Mfg 0.20 Motors Lighting 0.10 Fans 0.00 Compressed Air 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

Distribution Efficiency

Distribution system energy efficiency measures regulate voltage and upgrade systems to improve the efficiency of utility distribution systems and reduce line losses. Table 6 shows two methods for estimating distribution system potential for this analysis. For CPU’s 2013 assessment, the utility chose to estimate distribution potential using a ‘percent savings’. As previously described, this approach estimated savings for three of CPU’s substations which were analyzed as part of a region-wide distribution system efficiency and voltage optimization study. This method was utilized again for estimating distribution system conservation potential for the 2016-2035 planning period using CPU’s updated load forecast. The results of this method are shown in the column on the right in Table 5.

Clark Public Utilities—Conservation Potential Assessment 33

Distribution system potential was also estimated using the Council’s methodology. The Seventh Plan estimates distribution system potential based on end system energy sales. The results of the Council methodology approach are shown on the left side of Table 6.

Table 6 Distribution Efficiency – 20-Year Cost-Effective Achievable Potential End-System Sales Method Percent Savings Method 524.0 aMW (2016 estimated total system load) 0.82 % savings (based on 3 substations) 3.60% line loss 524.0 aMW (2016 estimated total system load) 505.2 aMW (2016 estimated end-system sales) 85% achievability 10% recent accomplishment 10% recent accomplishment 3.73 aMW 2.83 aMW

Distribution system conservation potential for the end-system sales method is shown in Figure 14. The cost estimates for distribution system potential shown in Table 7, in the next section, are also based on the end-system sales method.

Figure 14 Annual Distribution System Efficiency Potential

0.25

0.20

0.15 Major system improvements

aMW Minor system improvements 0.10 Reduce system voltage

0.05

0.00 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025

Cost

Budget costs can be estimated at a high level based on the incremental cost of the measures (Table 7). The assumptions used to estimate utility costs to acquire the conservation potential presented in this report include: 20% of measure capital cost for administrative expenditures and 35% of the incremental cost for incentives is assumed to be paid by the utility. A 20% allocation of measure costs to administrative expenses is a standard assumption for utility conservation programs. This figure was used in the Council’s analysis for the Sixth Power Plan. The figures shown in Table 7 are calculated using a 35% utility-share assumption. Both the

Clark Public Utilities—Conservation Potential Assessment 34

administrative cost allocation and the utility share assumptions are consistent with assumptions used in CPU’s 2013 CPA. Table 7 Cost for Economic Achievable Conservation Potential Utility First Year Cost ($2016) 2 Year 5 Year 10 Year 20 Year Residential $11,349,600 $29,896,500 $57,578,400 $110,090,300 Commercial $3,609,900 $9,665,000 $18,441,200 $28,138,200 Industrial $1,747,400 $4,343,400 $7,237,900 $9,223,300 Distribution Efficiency $104,100 $454,000 $1,417,300 $3,865,100 TOTAL $16,811,000 $44,358,900 $84,674,800 $151,316,900 Total ($/MWh, first year) $248 $248 $247 $252

This chart shows that CPU can expect to spend approximately $16.8 million to acquire estimated savings over the next two years. The bottom row of Table 7 shows the cost per MWh of first-year savings.

The cost estimates presented in this report are conservative estimates for future expenditures since they are based on historic values. Future conservation achievement may be more costly than historic conservation achievement since utilities often choose to implement the lowest cost programs first. In addition, as energy efficiency markets become more saturated, it may require more effort from CPU to acquire conservation through its programs. The additional effort may result in increased administrative costs.

Cost Scenarios

To provide a range of program costs over the planning period, EES tested a Low and a High cost scenario relative to the Base Case conservation potential scenario. For the Low scenario, the utility share of measure capital cost is reduced to 30 percent. A situation where the utility is responsible for a lower share of measure capital cost may result from higher conservation achievement through programs for which the customer is responsible for a higher fraction of measure cost. An example of this scenario would be if more conservation were achieved through commercial or industrial custom projects where lower incentives may be required to gain customer participation.

For the High Cost scenario, administrative costs were increased to 30 percent (compared with 20 percent in the Base Case). The High Cost scenario reflects the case where program administration costs may increase in order for CPU to connect with hard-to-reach customers.

Table 8 shows 2, 5, 10 and 20-year program costs for the Expected (Base Case), High and Low cost scenarios. Table 9 shows the cost per megawatt hour (first year savings) for each of the cost scenarios.

Clark Public Utilities—Conservation Potential Assessment 35

Table 8 Cost Scenarios for Base Case Economic Achievable Conservation Potential, $2016 Utility First Year Cost 2 Year 5 Year 10 Year 20 Year Expected Case $16,811,000 $44,358,900 $84,674,800 $151,316,900 Low Cost Case $15,282,600 $40,326,400 $76,977,000 $137,560,900 High Cost Case $19,867,400 $52,424,200 $100,070,100 $178,829,100

Table 9 Cost per MWh Savings (First Year) for Base Case Economic Achievable Conservation Potential, $2016 Utility First Year Cost ($/MWh) 2 Year 5 Year 10 Year 20 Year Expected Case $248 $248 $247 $252 Low Cost Case $225 $226 $224 $230 High Cost Case $293 $293 $292 $298

Table 9 costs are again presented as dollars per first year savings (MWh). These units do not consider the savings over the life of a measure, but they do provide an indication of the costs CPU could expect to acquire conservation going forward. Over the next two years, conservation programs are expected to cost between $225 and $293/MWh (first year savings). Overall, CPU can expect the biennium potential estimates presented in this report to cost between $15.3 and $19.9 million for utility incentives and administrative expenditures.

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Scenarios

The costs and savings discussed throughout the majority of this report describe the Base Case scenario. Under this scenario, annual potential for the planning period was estimated by applying the Council’s 20-year ramp rates to each measure and then adjusting the 20-year savings shape to accelerate potential in the first 10 years of the plan to more closely reflect CPU’s recent historic conservation achievement. The two-year target is lower than CPU’s recent achievement; however, CPU’s recent achievement is based on deemed measure savings values that are higher compared with the updated deemed savings values (those used in this study). For reference, some of the key parameters of the Base Case are listed below.

Base Case

 Base market price forecast  Residential growth = 1.4%  Commercial growth = 1.2%  Industrial growth = 0.6% 6  Population growth = 1.1%  Risk-mitigation credit = $32.46/MWh – Lost Opportunity; $22.72/MWh – Retrofit  Regional Conservation Act credit = 10%  Local system distribution credit = $31/kW-yr  Bulk system transmission and distribution credit = $23.14/kW-yr  Discount Rate = 4%

Scenarios

Three additional scenarios were developed to identify a range of possible outcomes and to account for uncertainties over the planning period. In addition to the Base Case scenario, this assessment tested a Low scenario and an Accelerated Base Case scenario. The Low scenario is relative to the Base Case.

Additional details about each of the scenarios are described in the following subsections.

6 Office of Financial Management. (2012). Washington State Growth Management Population Projections for Counties: 2010 to 2040. [Data files]. Retrieved from: http://www.ofm.wa.gov/pop/gma/projections12/projections12.asp

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Low Scenario

The Low conservation scenario evaluates conservation potential under conditions that reduce CPU’s exposure to market price volatility. For this scenario, the risk credits are reduced to $0/MWh. A situation in which CPU has risk of exposure to market prices may arise from the acquisition of less expensive resources to meet average energy and peak load requirements. All other assumptions for the Low scenario are the same as assumptions used in the Base Case scenario. Results of the Low scenario analysis are shown in Table 10. Under this scenario, 99.18 aMW of technically-achievable potential is available over the 20-year planning period.

Key parameters for the Low scenario include:

 Base market price forecast  Base Case growth assumptions  Risk-mitigation credits = $0/MWh

Table 10 Cost-Effective Achievable Potential – Low Scenario (aMW) 2 Year 5 Year 10 Year 20 Year

Residential 2.76 7.25 14.00 26.26 Commercial 1.68 4.51 8.56 13.87 Industrial 1.23 2.93 5.01 6.25 Distribution Efficiency 0.07 0.31 0.97 2.64 TOTAL 5.74 15.00 28.54 49.02

Accelerated Base Scenario

The Accelerated Base scenario represents a case where CPU is able to very quickly ramp up program savings, or savings from NEEA initiatives are realized sooner than expected. This scenario is modeled with more aggressive ramp rates in the first 10 years of the planning period, beyond what is presented in the Base Case; therefore, savings during the last 10 years of the planning period are reduced. Aside from adjusted ramp rates, the assumptions for the Accelerated scenario are identical to the Base Case. The Accelerated Base 2-year potential is approximately 77% higher compared with the Base Case 2-year potential (Table 11).

Table 11 Cost-Effective Achievable Potential – Accelerated Base Scenario (aMW) 2 Year 5 Year 10 Year 20 Year

Residential 10.36 25.64 38.14 46.68 Commercial 2.00 5.43 10.39 16.49 Industrial 1.23 2.93 5.01 6.25 Distribution Efficiency 0.10 0.44 1.37 3.73 TOTAL 13.69 34.44 54.91 73.15

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Scenario Summary

The 2, 5 and 10 and 20-year savings estimates for the three scenarios tested in this analysis are shown in Table 12, and Figure 12 graphs the Base Case, Low Case, and Accelerated scenarios. Figure 15 also shows the Base Case potential from CPU’s 2013 CPA, which is provided for reference. Potential is graphed for program years 1 to 20 to provide a better comparison between the 2013 and 2015 potential estimates.

Table 12 Cost-Effective Achievable Potential – Scenario Comparison (aMW) 2 Year 5 Year 10 Year 20 Year Base Case 7.74 20.41 39.14 68.42 Accelerated Base 13.69 34.44 54.91 73.15 Low Scenario 5.74 15.00 28.54 49.02

Figure 15 CPU Conservation Scenarios – Annual Potential (aMW)

8.0 7.0 6.0

5.0 4.0 aMW 3.0 2.0 1.0 - 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 Program Year

2015 Base Case 2013 Base Case Accelerated Base Low Scenario

Figure 15 shows that the Low scenario is lower on an annual basis compared with the Base Case scenario and the potential is approximately 30% lower over the planning period. This decrease is due to the difference between the number of measures that were cost-effective with the inclusion of risk credits in the avoided cost and the lower number of measures that were cost effective without risk credits.

The Accelerated scenario may be an achievable scenario for CPU, since the 2-year potential is lower than the utility’s historic annual conservation achievement. However, continuing to achieve similar levels of conservation would likely require that CPU continue to receive credit

Clark Public Utilities—Conservation Potential Assessment 39

for the same level of NEEA savings. In addition, decreases in deemed measure savings for residential weatherization will make it more difficult to maintain the utility’s historic achievement level going forward.

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Savings Shape Results

Energy efficiency is typically reported on an annual basis (kWh, MWh, or aMW). However, savings occur throughout the day and year at different levels. Annual savings for each measure are distributed to the applicable load segments for each month, based on the load shape affected by the measure. The measure load shapes are also used to estimate the value of the measure, based on projected time-differentiated savings. Load segments and load shapes used in this analysis can be found in the Mid-C and Load Shape file.

Figures 16 and 17 show total monthly energy savings by sector for the 20-year planning period. Figure 16 shows heavy load hour (HLH) savings and Figure 17 shows savings during light load hour (LLH) time periods. As would be expected, the savings are higher during the winter months. However, the winter savings are not as pronounced as winter savings estimates from previous assessments. The difference can be attributed to several factors: 1) total residential savings are substantially lower compared with previous assessments, 2) measure savings for residential weatherization measures, which have historically accounted for a significant portion of winter energy conservation, have been substantially reduced, and 3) commercial and industrial savings, which are more consistent on a monthly basis, have increased. The result of these changes is a seasonal load shape that is flatter compared with the overall shape presented in the 2013 CPA. Another factor affecting the 2015 CPA load savings shape is the introduction of cost-effective commercial heat pump measures, which provide savings in both winter and summer months.

Figure 16 CPU Monthly Energy Efficiency Savings, HLH

8.0

7.0

6.0

5.0 Residential

4.0 DEI aMW Industrial 3.0 Commercial 2.0

1.0

- Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

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Figure 17 CPU Monthly Energy Efficiency Savings, LLH

3.0

2.5

2.0

Residential

1.5 DEI aMW Industrial 1.0 Commercial

0.5

- Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Figure 18 shows the cumulative heavy load hour monthly energy savings over the first 10-years of the planning period. Figure 18 CPU Monthly Energy Efficiency Savings, HLH, Cumulative

30,000

25,000

20,000 Residential

15,000 Commercial Industrial

10,000 DEI MWh,Cumulative TOTAL

5,000

0

Jul-16 Jul-17 Jul-18 Jul-19 Jul-20 Jul-21 Jul-22 Jul-23 Jul-24 Jul-25

Jan-22 Jan-17 Jan-18 Jan-19 Jan-20 Jan-21 Jan-23 Jan-24 Jan-25 Jan-16 As would be expected, energy efficiency savings shapes are similar to the electric utility load shapes from a seasonal perspective.

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Peak Demand Savings

To estimate demand savings for this assessment, utility-specific load and coincidence factors by class (residential, commercial, etc.) were applied to cumulative monthly energy savings. The load and coincidence factors are consistent with the factors used in CPU’s 2014 Cost of Service Analysis (COSA) and are provided for reference in Appendix V (p. 67). This section presents summer and winter peak savings, coincident with CPU’s system. Figure 19 shows cumulative winter and summer peak demand savings over the planning period.7

Figure 19 Annual Peak Demand Savings, Cumulative (MW)

160 140 120

100

80 Winter Peak MW 60 Summer Peak 40 20 0

Figure 20 shows monthly cumulative peak demand savings for the 20-year planning period.

7 CPU’s annual winter peak is in January and the summer peak is in August.

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Figure 20 Monthly Peak Demand Savings, Cumulative (MW)

160

140

120

100

Residential

DEI

MW 80 Industrial 60 Commercial 40

20

- Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

The monthly demand savings profile shown in Figure 20 is similar to the energy savings profile. Figure 20 shows that demand savings are highest in December and are lower during the summer months. Table 13 shows cumulative annual energy savings and peak summer and winter demand savings for the 20-year planning period. The costs shown in Table 13 are annual, incremental utility costs (administrative expenditures and incentive costs). The costs were modeled with Base Case utility program assumptions.

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Table 13 Cumulative Peak Demand Savings with Associated Energy Savings and Costs Peak Demand Savings (MW) Energy Savings Winter Summer Year Cost (aMW) Peak Peak 2016 $8,187,136 3.78 7.80 5.21 2017 $8,623,781 7.74 15.98 10.68 2018 $8,916,097 11.84 24.45 16.36 2019 $9,231,937 16.09 33.24 22.26 2020 $9,399,990 20.41 42.19 28.25 2021 $9,053,053 24.60 50.87 34.06 2022 $8,568,796 28.60 59.14 39.62 2023 $8,128,665 32.38 67.02 44.89 2024 $7,571,716 35.90 74.39 49.80 2025 $6,993,526 39.14 81.17 54.37 2026 $6,804,858 42.19 87.87 58.50 2027 $6,764,653 45.20 94.53 62.61 2028 $6,721,513 48.17 101.14 66.67 2029 $6,688,176 51.11 107.72 70.70 2030 $6,663,754 54.03 114.28 74.72 2031 $6,646,316 56.94 120.83 78.71 2032 $6,588,592 59.81 127.34 82.68 2033 $6,588,080 62.68 133.84 86.65 2034 $6,588,077 65.55 140.35 90.62 2035 $6,588,256 68.42 146.86 94.58

The 20-year cumulative peak demand savings estimates for this assessment are 146.86 MW during CPU’s winter peak and 94.58 MW during the summer peak. For reasons previously described, the 2015 CPA peak demand savings estimates are lower compared with previous assessments.

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Summary

This report summarizes the results of the 2015 CPA conducted for Clark Public Utilities. The assessment provides estimates of energy savings by sector for the period 2016 to 2035 with a focus on the first 10 years of the planning period, as required by the EIA. The assessment considered a wide range of conservation resources that are reliable, available, and cost effective within the 20-year planning period.

Market conditions that include codes and standards changes, lower electricity market prices, and recent high achievements by CPU resulted in an assessment with lower potential compared with the prior assessment conducted in 2013. However, the 10 and 20-year potential for energy efficiency remain strong and energy efficiency is expected to remain an integral part of the CPU resource portfolio. Conservation remains the lowest cost and lowest risk resource and will serve to keep future electricity costs to a minimum.

Methodology and Compliance with State Mandates

The energy efficiency potential reported in this document is calculated using methodology consistent with the Council’s methodology for assessing conservation resources. Appendix III (p. 54) lists each requirement and describes how each item was completed. In addition to using methodology consistent with the Council’s Sixth Power Plan, this assessment utilized many of the measure assumptions that the Council developed for the Sixth and Seventh Regional Power Plans. Utility-specific data regarding customer characteristics, service-area composition, and historic conservation achievements were used, in conjunction with the measures identified by the Council, to determine available energy-efficiency potential. Conservation potential was assessed for multiple periods: 2 years, 5 years, 10 years, and 20 years. This close connection with the Council methodology enables compliance with the Washington EIA.

Three types of energy-efficiency potential were calculated: technical, economic, and achievable. Most of the results shown in this report are the “achievable” potential, or the potential that is economically achievable in the CPU service territory. The economic and achievable potential considers savings that will be captured through utility program efforts, market transformation and implementation of codes and standards. Often, realization of full savings from a technology, particularly a new or emerging technology, will require efforts across all three areas. Historic efforts to measure the savings from codes and standards have been limited, but regional efforts to identify and track savings are increasing as they become an important component of the efforts to meet aggressive regional conservation targets.

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Conservation Targets

The EIA states that utilities must establish a biennial target that is “no lower than the qualifying utility’s pro rata share for that two year period of its cost-effective conservation potential for the subsequent ten-year period.”8 However, the State Auditor’s Office has stated that:

The term pro-rata can be defined as equal portions but it can also be defined as a proportion of an “exactly calculable factor.” For the purposes of the Energy Independence Act, a pro-rata share could be interpreted as an even 20 percent of a utility’s 10 year assessment but state law does not require an even 20 percent.9

The State Auditor’s Office expects that qualifying utilities have analysis to support targets that are more or less than the 20 percent of the ten year assessments. This document serves as support for the target selected by Clark Public Utilities and approved by its Commission.

Summary

This study shows a range of conservation target scenarios. These scenarios are estimates based on the set of assumptions detailed in this report and supporting documentation and models. Due to the uncertainties discussed in the Introduction section of this report, actual available and cost-effective conservation may vary from the estimates provided in this report.

8 RCW 19.285.040 Energy conservation and renewable energy targets.

9 State Auditor’s Office. Energy Independence Act Criteria Analysis. Pro-Rata Definition. CA No. 2011-03. https://www.sao.wa.gov/local/Documents/CA_No_2011_03_pro-rata.pdf

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References

Ecotope Inc. 2012. 2011 Residential Building Stock Assessment: Single-Family Characteristics and Energy Use. Seattle, WA: Northwest Energy Efficiency Alliance.

Ecotope Inc. 2012. 2011 Residential Building Stock Assessment: Manufactured Home Characteristics and Energy Use. Seattle, WA: Northwest Energy Efficiency Alliance.

Ecotope Inc. 2012. 2011 Residential Building Stock Assessment: Multi-Family Characteristics and Energy Use. Seattle, WA: Northwest Energy Efficiency Alliance.

Navigant Consulting. 2014. Northwest Commercial Building Stock Assessment: Final Report. Portland, OR: Northwest Energy Efficiency Alliance.

Northwest Power and Conservation Council. Achievable Savings: A Retrospective Look at the Northwest Power and Conservation Council’s Conservation Planning Assumptions. August 2007. Retrieved from: http://www.nwcouncil.org/library/2007/2007-13.htm.

Northwest Power and Conservation Council. 7th Power Plan Technical Information and Data. April 13, 2015. Retrieved from: http://www.nwcouncil.org/energy/powerplan/7/technical

Northwest Power and Conservation Council. 6th Power Plan Supply Curve Files. December 10, 2009. Retrieved from: http://www.nwcouncil.org/energy/powerplan/6/supplycurves/default.htm

Northwest Power and Conservation Council. Sixth Northwest Conservation and Electric Power Plan. Feb 2010. Retrieved from: http://www.nwcouncil.org/energy/powerplan/6/default.htm

Northwest Power and Conservation Council. Northwest Industrial Supply Curve. January 14th, 2008. Retrieved from: http://www.nwcouncil.org/energy/powerplan/6/supplycurves/ind/ISC%20Model%20Revie w%20R4.pdf

Northwest Power and Conservation Council. System Optimization Measures Guide. January 14th, 2008. Retrieved from: http://www.nwcouncil.org/energy/powerplan/6/supplycurves/ind/Systems%20Whole%20P Plan%20Optimization%20Overview%20R8.pdf

Office of Financial Management. (2012). Washington State Growth Management Population Projections for Counties: 2010 to 2040. [Data files]. Retrieved from: http://www.ofm.wa.gov/pop/gma/projections12/projections12.asp

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State Auditor’s Office. Energy Independence Act Criteria Analysis. Pro-Rata Definition. CA No. 2011-03. Retrieved from: https://www.sao.wa.gov/local/Documents/CA_No_2011_03_pro- rata.pdf

Washington State Energy Code, Wash. (2012)

Washington State Legislature. RCW 19.285.040 Energy conservation and renewable energy targets. Retrieved from: http://apps.leg.wa.gov/rcw/default.aspx?cite=19.285.040

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Appendix I – Acronyms

aMW –Average Megawatt BPA – Bonneville Power Administration CFL – Compact Fluorescent Light Bulb CPU – Clark Public Utilities EIA – Energy Independence Act HLH – Heavy load hour energy HVAC – Heating, ventilation and air-conditioning kW – kilowatt kWh – kilowatt-hour LED – Light-emitting diode LLH – Light load hour energy MF –Multi-Family MH –Manufactured House MW –Megawatt MWh –Megawatt-hour NEEA – Northwest Energy Efficiency Alliance NPV – Net Present Value O&M – Operation and Maintenance RPS – Renewable Portfolio Standard UC – Utility Cost

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Appendix II – Glossary

6th Power Plan: Sixth Northwest Conservation and Electric Power Plan, Feb 2010. A regional resource plan produced by the Northwest Power and Conservation Council (Council). Average Megawatt (aMW): Average hourly usage of electricity, as measured in megawatts, across all hours of a given day, month or year. Avoided Cost: Refers to the cost of the next best alternative. For conservation, avoided costs are usually market prices. Achievable Potential: Conservation potential that takes into account how many measures will actually be implemented. For lost-opportunity measures, there is only a certain % of expired units or new construction for a specified time frame. The Council uses 85 and 65 % achievability rates for retrofit and lost-opportunity measure respectively. Sometimes achievable potential is a % of economic potential, and sometimes achievable potential is defined as a % of technical potential. Conservation Calculator: Refers to Excel program developed by the Council which calculates conservation potential for Northwest utilities based on their share of the regional load. Cost Effective: A conservation measure is cost effective if its present-value benefits are greater than its present-value costs. The primary test is the Total Resource Cost test (TRC), in other words, the present value of all benefits is equal to or greater than the present value of all costs. Benefits and costs are for society as whole. CTED (Department of Community Trade and Economic Development): CTED Energy Policy Division helps deliver an economically and environmentally sound energy future to the State of Washington and its citizens. The department provides information, analysis and support and assists in developing energy policies and programs. Economic Potential: Conservation potential that considers the cost and benefits and passes a cost-effectiveness test. Levelized Cost: Resource costs are compared on a levelized-cost basis. Levelized cost is a measure of resource costs over the lifetime of the resource. Evaluating costs with consideration of the resource life standardizes costs and allows for a straight comparison. Lost Opportunity: Lost-opportunity measures are those that are installed as new construction or at the end of the life of the unit. Examples include weatherization, heat-pump upgrades, appliances, or premium HVAC in commercial buildings. MW (megawatt): 1,000 kilowatts of electricity. The generating capacity of utility plants is expressed in megawatts. Non-Lost Opportunity: Measures that can be acquired at any time, such installing low-flow shower heads.

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Northwest Energy Efficiency Alliance (NEEA): The alliance is a unique partnership among the Northwest region's utilities, with the mission to drive the development and adoption of energy- efficient products and services. Northwest Power and Conservation Council “The Council”: The Council develops and maintains a regional power plan and a fish and wildlife program to balance the Northwest's environment and energy needs. Their three tasks are to: develop a 20-year electric power plan that will guarantee adequate and reliable energy at the lowest economic and environmental cost to the Northwest; develop a program to protect and rebuild fish and wildlife populations affected by hydropower development in the Columbia River Basin; and educate and involve the public in the Council’s decision-making processes. Regional Technical Forum (RTF): The Regional Technical Forum (RTF) is an advisory committee established in 1999 to develop standards to verify and evaluate conservation savings. Members are appointed by the Council and include individuals experienced in conservation program planning, implementation and evaluation. Renewable Portfolio Standards: Washington state utilities with more than 25,000 customers are required to meet defined %ages of their load with eligible renewable resources by 2012, 2016, and 2020. Retrofit (discretionary): Retrofit measures are those that are replaced at any time during the unit’s life. Examples include lighting, shower heads, pre-rinse spray heads, or refrigerator decommissioning. Technical Potential: Technical potential includes all conservation potential, regardless of cost or achievability. Technical potential is conservation that is technically feasible. Total Resource Cost Test (TRC): This test is used by the Council and nationally to determine whether or not conservation measures are cost effective. A measure passes the TRC if the present value of all benefits (no matter who receives them) over the present value of all costs (no matter who incurs them) is equal to or greater than one.

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Appendix III – Documenting Conservation Targets

References:

1) Report – “Clark Public Utilities 2015 Conservation Potential Assessment”. Draft Report – September 23, 2015. 2) Model – “Clark CPA 2015 - Base.xlsm” and supporting files a. MC_and_Loadshape_Clark Base.xlsm – referred to as “MC file” – contains price and load shape data

WAC 194-37-070 Documenting Development of Conservation Targets; Utility Analysis Option NWPCC Methodology EES Consulting Procedure Reference a) Analyze a broad range of All of the Council's current energy Model – “All Measures” energy efficiency measures efficiency measures (Sixth and worksheet considered technically feasible. Seventh Plan measures) were evaluated to determine which had greater benefits than costs. b) Perform life-cycle cost analysis The life-cycle cost analysis was Model – supporting files include of measures or programs, performed using the Council’s all of the ProCost files used in the including the incremental ProCost model. Incremental costs, Sixth Plan. The life-cycle cost savings and incremental costs savings, and lifetimes for each calculations/methods are identical of measures and replacement measure were the basis for this to those used by the council. measures where resources or analysis. The Council and RTF measures have different assumptions were utilized. measure lifetimes. c) Set avoided costs equal to a A regional market price forecast for Report – See Figure 3 and forecast of regional market the planning period was created and associated discussion. Also see prices, which represents the provided by CPU consistent with Appendix IV. cost of the next increment of their IRP. Model – See MC File (“Clark Base” available and reliable power worksheet). supply available to the utility for the life of the energy efficiency measures to which it is compared. d) Calculate the value of the The Council's Sixth Plan default Model – See MC file for load energy saved based on when it measure load shapes were used to shapes. The ProCost files handle is saved. In performing this calculate time of day usage and the calculations. calculation, use time measure values were weighted differentiated avoided costs to based upon peak and off-peak conduct the analysis that pricing. This was handled using the determines the financial value Council’s ProCost program so it was of energy saved through handled in the same way as the Sixth conservation. Power Plan models.

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WAC 194-37-070 Documenting Development of Conservation Targets; Utility Analysis Option NWPCC Methodology EES Consulting Procedure Reference e) Conduct a total resource cost Cost analysis was conducted Model – the Clark Public Utilities analysis that assesses all costs according to the Council's CPA main file pulls in all of the and all benefits of conservation methodology. Capital cost, results, including the BC ratios. measures regardless of who administrative cost, annual O&M However, the TRC analysis is done pays the costs or receives the cost and periodic replacement costs at the lowest level of the model in benefits. The NWPCC identifies were all considered on the cost side. the ProCost files. conservation measures that Energy, non-energy, O&M and all pass the total resource cost test other quantifiable benefits were as economically achievable. included on the benefits side. The Total Resource Cost (TRC) benefit cost ratio was used to screen measures for cost-effectiveness (I.e., those greater than 1 are cost- effective). f) Identify conservation measures Benefits and costs were evaluated Model – BC Ratios are calculated that pass the total resource using multiple inputs; benefit was at the ProCost level and passed up cost test, by having a then divided by cost. Measures to the sector and total levels of benefit/cost ratio of one or achieving a BC ratio of >=1 were the model. greater as economically tallied. These measures are achievable. considered achievable and cost- effective (or “economically achievable”). g) Include the increase or Operations and maintenance costs Model – the ProCost files contain decrease in annual or periodic for each measure were accounted the same assumptions for periodic operations and maintenance for in the total resource cost O&M as the Council and RTF. costs due to conservation according to the Council's measures. assumptions. h) Include deferred capacity Deferred capacity expansion benefits Model – this value can be found expansion benefits for were given a benefit of $31/kW-yr on the ProData page of each transmission and distribution for local and $23.14/kW for bulk ProCost file. systems in its cost-effectiveness transmission in the cost- analysis. effectiveness analysis. This is the same assumption used by the Council in the development of the Seventh Power Plan. i) Include all nonpower benefits Quantifiable non-energy benefits Model – the ProCost files contain that a resource or measure may were included where appropriate. the same assumptions for provide that can be quantified Assumptions for non-energy benefits nonpower benefits as the Council and monetized. are the same as in the Councils and RTF. The calculations are Sixth/Seventh Power Plan. Non- handled in exactly the same way. energy benefits include, for example, water savings from clothes washers.

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WAC 194-37-070 Documenting Development of Conservation Targets; Utility Analysis Option NWPCC Methodology EES Consulting Procedure Reference j) Include an estimate of program Total costs were tabulated and an Model – this value can be found administrative costs. estimated 20% of total was assigned on the ProData page of each as the administrative cost. This value ProCost file. is consistent with regional average and BPA programs. The 20% value was used in the Fifth, Sixth, and Seventh Power plans. k) Discount future costs and Discount rates were applied to each Model – this value can be found benefits at a discount rate measure based upon the Council's on the ProData page of each based on a weighted, after-tax, methodology. Real discount rate = ProCost file. cost of capital for utilities and 4%, based on the Council’s most their customers for the recent analyses. measure lifetime. l) Include estimates of the The assessment conducted for CPU Model – these factors can be achievable customer was for the 20-year planning period, found on some of the hidden conservation penetration rates thus 85% for retrofit measures and worksheets in the main model for retrofit measures and for 65% for lost opportunity measures (e.g., “Applicability Table DHW lost-opportunity (long-lived) were used to determine potential. Light”). These tables show the measures. The NWPCC's 85% value and how it is applied to twenty-year achievable the number of units. For the penetration rates, for use when commercial sector, these a utility assesses its twenty-year applicability values can be found potential, are eighty-five % for in the “SC” worksheets of the retrofit measures and sixty-five ProCost files. % for lost opportunity measures achieved through a mix of utility programs and local, state and federal codes and standards. The NWPCC's ten- year achievable penetration rates, for use when a utility assesses its ten-year potential, are sixty-four % for nonlost opportunity measures and twenty-three % for lost- opportunity measures; the weighted average of the two is a forty-six % ten-year achievable penetration rate m) Include a ten % bonus for A 10% bonus was added to all Model – this value can be found conservation measures as measures in the model parameters on the ProData page of each defined in 16 U.S.C. § 839a of per the Conservation Act. ProCost file. the Pacific Northwest Electric Power Planning and Conservation Act.

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WAC 194-37-070 Documenting Development of Conservation Targets; Utility Analysis Option NWPCC Methodology EES Consulting Procedure Reference n) Analyze the results of multiple Accelerated, low, and high scenarios Report – see “Scenario Results” scenarios. This includes testing were run and plotted next to the section and Figure 20. scenarios that accelerate the base-case scenario. Ramp rates Model – there is a separate model rate of conservation acquisition were also utilized to adjust for CPU’s for each scenario. In addition, in the earlier years. programs. there is an “Accelerated Base” model that further accelerates the ramp rates of the base case in the early years. o) Analyze the costs of estimated The avoided cost data include Multiple scenarios were analyzed future environmental estimates of future high, medium, and these scenarios include externalities in the multiple and low CO2 costs. different levels of estimated costs scenarios that estimate costs and risk. and risks.

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Appendix IV – Avoided Cost and Risk Exposure

EES Consulting (EES) has conducted Conservation Potential Assessment (CPA) for Clark Public Utilities (CPU) for the period 2016 through 2035 as required under RCW 19.285 and WAC 194.37. According to WAC 197.37.070, CPU must evaluate the cost-effectiveness of conservation by setting avoided costs equal to a forecast of regional market prices. For the purposes of the 2015 CPA, EES has prepared a forecast of market prices for the Mid-Columbia trading hub. This appendix summarizes the methodology and results of the market price forecast and compares the forecast to the market forecast used for CPU’s 2013 CPA (2014/15 biennium). Methodology

2016-2021

For the period January 2016 through December 2021 projected monthly on- and off-peak market prices were provided by CPU’s scheduling agent. CPU’s scheduling agent provides CPU with forward price projections on a daily basis. The forward market prices upon which the avoided costs are based were provided March 24, 2015. The forward market prices include an average annual escalation rate of market prices is 7.9 % over the 6-year period 2016 through 2021.

2022-2035

For the period January 2022 through December 2035, EES calculated projected market prices using the methodology described below.

Merchant natural gas-fired power plants operate on the margin in the Northwest. As the market price of electricity is usually set by the cost of the marginal unit, EESC developed the market price forecast using a forecast of natural gas prices and projected market-implied heat rates or sparks spread. The projected market-implied heat rates reflect the average efficiency of gas-fired power plants in the Pacific Northwest. Projections are based on historic market- implied heat rates which are calculated by dividing historic Mid-Columbia (Mid-C) wholesale market prices by historic Sumas natural gas prices. EESC developed a natural gas price forecast based on NYMEX forward gas prices for the Henry Hub trading hub, Sumas basis differentials, and projected market heat rates. The following steps were taken to produce the wholesale electric load forecast for the 2015 CPA:

1. Forward prices for natural gas at Henry Hub are available through February 2025. A 2.5 % annual growth rate is assumed after February 2025. 2. The Sumas basis differential is used to adjust the Henry Hub forward prices to Northwest prices. Sumas forward gas prices are equal to NYMEX forward prices (Henry Hub) plus the Sumas basis. The Sumas basis forward curve is available through December 2020. The monthly basis for Sumas is held constant after December 2020.

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3. Projected monthly market-implied heat rates are applied to the Sumas forward gas price forecast to result in a forecast of Mid-C prices. Or, Mid-C prices are equal to Sumas forward prices multiplied by forecast heat rates. 4. Projected heat rates are based on historic heat rates (Mid-C wholesale electricity prices divided by Sumas natural gas prices). 5. Monthly market-implied heat rates are escalated based on the average escalation rate in 2017 through 2021. 6. Forecast Mid-C prices are benchmarked against other market price forecasts.

Based on the methodology detailed above market prices are projected to escalate annually at an average rate of 5.2 over the 14-year period 2022 through 2035. Results

Figure A-1 illustrates the resulting monthly, diurnal market price forecast. The levelized value of market prices over the study period is $42.71/MWh assuming a 4% real discount rate. The average annual growth rate beginning in 2024 is 5%.

Figure A-1 Forecast Mid-Columbia Market Prices $140

$120

$100

$80

$60 $2015/MWh $40

$20

$0

Jul-21 Jul-32

Jan-16 Jan-27

Jun-22 Jun-33

Oct-18 Oct-29

Apr-24 Apr-35

Sep-19 Feb-26 Sep-30

Dec-16 Dec-27

Aug-20 Aug-31

Nov-17 Nov-28

Mar-25

May-23 May-34

On-Peak Off-Peak

The 2015 market price forecast is lower than the market price forecast used in CPU’s most recent CPA. Figure A-2 compares the two forecasts.

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Figure A-2 Market Price Forecast Comparison, $Real $100 $90 $80 $70

$60 $50

$/MWh $40 $30 $20 $10

$0

2016 2025 2034 2017 2018 2019 2020 2021 2022 2023 2024 2026 2027 2028 2029 2030 2031 2032 2033 2035

2015 CPA 2013 CPA

The 2015 price forecast is 24% lower compared with the 2013 forecast due to changes in market conditions mainly due to decreases in natural gas prices. Figure A-3 illustrates historic natural gas spot prices.10 The average 2015 natural gas price ($2.90/MMBtu) is 25% lower compared with the gas price at the same time of year in 2013 ($3.84/MMBtu).

10 U.S. Energy Information Administration. Natural Gas Data. Henry Hub Natural Gas Spot Price. Accessed April 23, 2015. http://www.eia.gov/dnav/ng/hist/rngwhhdm.htm

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Figure A-3 Henry Hub Natural Gas Price History $7.00

$6.00

$5.00

$4.00

$3.00 $2015/MMBtu $2.00

$1.00

$0.00

Benchmarking

Figure A-4 compares the January 2016 through September 2017 EES forecast with the forecast included in BPA’s Initial Proposal for FY16-17 rates. Since EES relied on projected market prices during this 21-month period the “EES” prices shown in Figure A-4 are equal to CPU power marketer’s forward market prices as of March 24, 2014. The monthly shapes are somewhat similar although BPA’s forward prices include more volatility in the winter months of 2017. The difference in overall price levels is due to the fact that natural gas prices decreased between the time that BPA developed its forecast in the fall of 2014 and March 24, 2015, the day CPU’s power marketer developed its forward price projection.

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Figure A-4 Comparison with BPA Forecast $50 $45 $40

$35 $30 $25 $20 $2015/MWh $15 $10 $5

$0

Jul-16 Jul-17

Jan-16 Jan-17

Jun-16 Jun-17

Oct-16

Apr-16 Apr-17

Sep-16 Feb-16 Feb-17 Sep-17

Dec-16

Aug-16 Aug-17

Nov-16

Mar-16 Mar-17

May-16 May-17

EES On-Peak EES Off-Peak BPA On-Peak BPA Off-Peak

Risk

The avoided cost forecast is used in CPU’s CPA to evaluate energy efficiency measure cost- effectiveness. As part of the cost-effectiveness analysis in the Northwest Power and Conservation Council’s (Council) 6th Power Plan,11 risk adders are included to account for market price risk (inclusive of deferred capacity investments to production, environmental factors, and fuel price risk). In order to evaluate market price risk in CPU’s CPA, two conservation scenarios are evaluated: Base and Low. These scenarios model market price risk deterministically by evaluating energy efficiency under different market price levels with the inclusion of risk adders. Risk adders for the 2015 CPA scenarios are discussed below, but first background information on CPU’s market price risk exposure is provided.

Load Resource Balance

CPU regularly updates its integrated resource plan to compare projected loads and resources over a study period of 20 years. These loads are met with federal and non-federal resources, including demand side resources. In October 2011, CPU began purchasing power from the Bonneville Power Administration (BPA) as a Slice/Block customer under a power contract signed in December 2008. As a Slice/Block customer, CPU purchases an approximate 2.2% share of the real-time capability of the Federal Based System (FBS) and monthly flat blocks of energy. CPU expects average annual supply from the Slice/Block contract to be between 294 to 310 aMW, with peak capability of 508 MW. Under average water conditions, it is estimated

11 Northwest Power and Conservation Council. Sixth Northwest Power Plan. February 2010. https://www.nwcouncil.org/energy/powerplan/6/plan/

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that BPA resources could provide up to 70% of CPU’s power requirements through the end of the contract term in 2028. As a Slice/Block customer CPU relies on scheduled output from the FBS as well as market transactions to follow load.

CPU owns and operates the River Road Generating Plant which is a 248 MW natural gas-fired power plant. The utility estimates that this resource will provide approximately 225 aMW of average annual generation to serve loads for the foreseeable future. Output from the River Road plant meets approximately 37% of CPU’s current annual average load requirements. In 2009, CPU signed a contract to purchase the entire output of the Combine Hills II wind project for a 20-year term, which began in January 2010. Average annual supply from this resource is approximately 18 aMW. CPU is under contract to purchase 18% of the production capability of the Packwood Hydroelectric Project. This hydroelectric project is owned and operated by Energy Northwest and CPU’s share provides approximately 1.1 aMW of average annual energy to serve utility loads.

To evaluate resource adequacy and resource portfolio impacts under a range of scenarios, CPU evaluates average annual energy and peak energy requirements under expected, high and low load growth scenarios. The utility evaluates electric power requirements based on expected output from its existing resources. As reported in CPU’s 2014 IRP, the utility expects to have surplus energy on an annual basis through 2033 under the base case load forecast. Figure A-5 shows expected annual energy from existing resources and CPU’s Base Case system load forecast.12

12 The base case system load forecast includes distribution system losses of 3.6%. The load forecast does not include projected savings from conservation/DSM programs. The base case long-term growth forecast annual growth rate is 1.1%.

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Figure A-5 CPU Load Resource Balance, Base Case Forecast (Annual Average Energy)

Figure A-5 shows that under these conditions, CPU expects to have 18 aMW of surplus energy on an annual basis through 2033. This scenario, however, depends on CPU acquiring approximately 5 aMW of conservation per year, as estimated in the utility’s 2013 CPA. Excluding projected conservation and DSM resource acquisition, the utility’s annual energy requirements would exceed its resources beginning in 2018.

Figure A-6 shows annual peak requirements under the base case load growth scenario. The top line shows power requirements under the base case scenario, plus a 12% planning margin. This planning margin is included to account for resource output variability, weather events, and other impacts which may affect CPU’s ability to meet its annual peak demand.

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Figure A-6 CPU Load Resource Balance, Base Case Forecast (Annual Peak Energy)

Figure A-6 shows that CPU has an approximate 320 MW annual peak load deficit in 2015 under base case load growth. The chart shows demand savings from conservation and DSM resources at 14 MW in 2015 and increasing to 165 MW in 2033.

All of CPU’s potential resource strategies for meeting incremental peak requirements include acquisition of conservation/DSM resources. Pursuing conservation will help CPU meet its peak demand requirements and will reduce the need for additional resources to meet annual energy requirements.

Avoided Cost and Risk Discussion

The avoided cost forecast developed for the 2015 CPA is lower compared to the 2013 CPA forecast by about 24%. The lower prices are due mainly to the current lower level of natural gas prices. This lower avoided cost may result in some conservation measures no longer crossing the cost-effective threshold. A risk credit is included in the Base Case scenario and accounts for deferred capacity investments (for production). The risk credit included in the 2015 CPA is adjusted to reflect the fact that forward market prices are less than those included in the 2013 CPA and the Sixth Power Plan. The risk mitigation credit utilized in the 2015 CPA is calculated as follows:

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 Risk mitigation credit included in 6th Power Plan and 2011 CPA = $35/MWh  Market prices included in 2013 CPA as a percent of market prices included in 2011 CPA = 85%  Risk Mitigation Credit Included in 2013 CPA = $35/MWh x 0.85 = $29.75/MWh  Market prices included in 2015 CPA as a percent of market prices included in 2013 CPA = 76.4%  Risk mitigation credit included in 2015 CPA = $29.75/MWh x 0.764 = $22.72/MWh

As shown above, the risk mitigation credit is $22.72/MWh (for retrofit measures) compared with the Council’s $35/MWh ($2006). The same methodology is used to adjust the lost opportunity measure risk credit from $50/MWh in the Sixth Power Plan to $32.46/MWh in the 2015 CPA.

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Appendix V – CPU Load and Coincidence Factors

Tables A-1 through A-3 show the monthly load and coincidence factors used to determine utility peak demand savings for the energy savings potential estimated for this assessment. The residential, commercial, industrial and street lighting load and coincidence factors are consistent with assumptions used in CPU’s 2014 COSA. To determine distribution system demand savings, each residential, commercial and industrial factor was weighted based on the distribution of energy savings for each month and year of the planning period then applied to distribution system energy savings. The distribution system factors shown in the table below are based on the 20-year monthly averages. Table A-1 CPU Individual Load Factor Residential Commercial Industrial Street Lighting Distribution

January 25.65% 43.50% 79.87% 65.00% 35.09% February 20.65% 46.00% 79.95% 55.00% 32.81% March 16.65% 39.41% 76.49% 50.00% 28.92% April 15.65% 42.30% 77.22% 45.00% 30.17% May 15.65% 39.59% 77.11% 40.00% 30.56% June 12.65% 40.52% 76.69% 35.00% 30.47% July 12.65% 41.05% 77.19% 40.00% 30.54% August 12.65% 41.70% 79.30% 45.00% 31.29% September 16.65% 41.53% 75.92% 50.00% 32.35% October 16.65% 40.22% 76.77% 55.00% 30.41% November 19.65% 42.12% 76.95% 60.00% 31.07% December 20.65% 43.91% 76.68% 65.00% 31.26%

Table A-2 CPU Group Coincidence Factor Residential Commercial Industrial Street Lighting Distribution

January 30.00% 71.58% 99.91% 100.00% 46.84% February 36.00% 70.67% 99.90% 100.00% 50.94% March 34.00% 73.62% 99.86% 100.00% 51.33% April 32.00% 70.79% 99.90% 100.00% 50.71% May 30.00% 65.05% 99.78% 100.00% 49.44% June 25.00% 64.14% 99.88% 100.00% 48.10% July 25.00% 64.17% 99.97% 100.00% 47.97% August 30.00% 70.77% 99.92% 100.00% 53.19% September 33.00% 72.69% 99.92% 100.00% 54.52% October 35.00% 80.25% 99.93% 100.00% 55.52% November 30.00% 82.12% 99.94% 100.00% 50.13% December 38.00% 80.22% 99.95% 100.00% 53.95%

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Table A-3 CPU System Coincidence Factor Residential Commercial Industrial Street Lighting Distribution

January 92.00% 93.71% 95.00% 100.00% 92.97% February 92.00% 93.72% 95.00% 100.00% 92.98% March 92.00% 92.74% 93.00% 0.00% 92.56% April 88.00% 88.74% 89.00% 0.00% 88.56% May 86.00% 86.00% 86.00% 0.00% 86.22% June 85.00% 85.00% 86.00% 0.00% 85.34% July 80.00% 80.76% 85.00% 0.00% 81.09% August 80.00% 80.75% 84.99% 0.00% 81.13% September 80.00% 80.75% 84.99% 0.00% 81.13% October 85.00% 85.76% 89.99% 0.00% 86.08% November 88.00% 88.76% 90.00% 100.00% 88.67% December 92.00% 92.74% 93.00% 100.00% 92.52%

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Appendix VI – Measure List

This appendix provides a high-level measure list of the energy efficiency measures evaluated in the 2015 CPA. The CPA evaluated approximately 1,400 individual measures; the measure list does not include each individual measure rather it summarizes the major measure bundles. Specifically, utility conservation potential is modeled based on incremental costs and savings of individual measures. Individual measures are then combined into measure “bundles” to more realistically reflect utility-conservation program organization and offerings. For example, single-family attic insulation measures are modeled for a variety of upgrade increments: R-0 to R-38, R-0 to R-49, or R-19 to R-38. The increments make it possible to model measure savings and costs at a more precise level. Each of these individual measures are then bundled across all housing types to result in one measure group: attic insulation.

The measure list used in this CPA was developed based on information from the Regional Technical Forum (RTF) and the Northwest Power and Conservation Council (Council). The RTF and the Council continually maintain and update a list of regional conservation measures based on new data, changing market conditions, regulatory changes, and technological developments. In preparation for the Seventh Power Plan, scheduled to be released near the end of 2015, the Council and RTF have been revising Sixth Power Plan regional conservation measures. Costs, savings, applicability, and other factors have been revised for individual measures and many measures have been added or removed. The measure list provided in this appendix includes the most up-to date information available at the time this CPA was developed.

The following tables list the conservation measures (at the bundle level or lower) that were used to model conservation potential presented in this draft report. Measure bundles in red are new in the Seventh Plan. Measure data was sourced from the Council’s Seventh Plan workbooks, the RTF’s Unit Energy Savings (UES) workbooks, and some of data came from the Bonneville Power Administration (BPA). Please note that some measures may not be applicable to an individual utility’s service territory based on characteristics of the utility’s customer sectors.

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Table A-4 Residential End Uses and Measures

End Use Measures Data Source Clothes Washer 7th Plan Heat Pump Dryer 7th Plan Dishwasher 7th Plan Appliances Refrigerator 7th Plan Freezer 7th Plan Oven 7th Plan Microwave Oven 7th Plan Advanced Power Strips RTF LCD Display Monitor 7th Plan Consumer Electronics Desktop Computer 7th Plan Set Top Box RTF LED General Purpose and Dimmable 7th Plan LED Decorative and Mini-Base 7th Plan Lighting LED Globe 7th Plan LED Reflectors and Outdoor 7th Plan LED Three-Way 7th Plan Attic Insulation 7th Plan, BPA Floor Insulation 7th Plan, BPA Envelope - Retro Wall Insulation 7th Plan, BPA Window Upgrade 7th Plan, BPA

WiFi Enabled Thermostats 7th Plan Attic Insulation RTF Floor Insulation RTF Wall Insulation RTF Envelope - New Below Grade Wall Insulation RTF Slab Insulation RTF Vaulted Ceiling Insulation RTF Window Glazing RTF Cooling Window Air Conditioner 7th Plan

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Table A-4 (cont’d) Residential End Uses and Measures

End Use Measures Data Source Ductless Heat Pump 7th Plan Heat Pump/Ductless Heat Pump Air Source Heat Pump 7th Plan Variable Capacity Central Heat Pump 7th Plan Heat Pump Water Heater 7th Plan Efficient Tank 7th Plan Water Heating Showerhead 7th Plan Bathroom Aerator 7th Plan Solar Water Heating Solar Water Heater 7th Plan

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Table A-5 Commercial End Uses and Measures

End Use Measures Data Source Bi-Level Stairwell Lighting 7th Plan Interior Lighting Controls 7th Plan Low Power Fluorescent Lamps 7th Plan Lighting Lighting Power Density (LPD) Package 7th Plan Exterior Building Lighting 7th Plan Parking Garage Lighting 7th Plan Light Emitting Capacitor Exit Sign 7th Plan Anti-Sweat Heater Controls 7th Plan ECM Controllers on Walk-In Evaporator Motors 7th Plan Floating Head Pressure Control 7th Plan Grocery Retrocommissioning 7th Plan Refrigeration LED Case Lighting 7th Plan LED Motion Sensors on Display Case 7th Plan Replace Shaded Pole with ECM in Walk-in Cooler 7th Plan Strip Curtains: Walk-In Coolers/ Freezers 7th Plan Water Cooler Controls 7th Plan Demand Control Ventilation - Restaurant Hoods 7th Plan Pre-Rinse Spray Valve 7th Plan Combination Oven 7th Plan Food Preparation Convection Oven 7th Plan Hot Food Holding Cabinet 7th Plan Steamer 7th Plan Advanced Rooftop Controller 7th Plan HVAC Controls Energy Management 7th Plan Demand Control Ventilation 7th Plan Electrically Commutated Motors on Variable 7th Plan Air Volume Boxes (ECM-VAV) 7th Plan Ventilation Low Pressure Distribution Complex HVAC RTF Variable Refrigerant Flow 7th Plan Web-Enabled Thermostats 7th Plan

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Table A-5 (cont’d) Commercial End Uses and Measures

End Use Measures Data Source

Heat Pump/Ductless Heat Pump Ductless Heat Pump 7th Plan Secondary Glazing System - Windows 7th Plan Envelope Roof Insulation RTF Rooftop Units Economizer 7th Plan Compressed Air Improvements 7th Plan Compressed Air Compressed Air Controls 7th Plan Chillers Variable speed chillers RTF Networked Computer Control RTF PC Network Power Supply Smart Plug Power Strips 7th Plan Motors Motors - Rewind 7th Plan Showerheads 7th Plan, RTF Water Heating Water Heater Tanks 7th Plan Data Centers Data Center Measure Suite 7th Plan

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Table A-6 Industrial End Uses and Measures

End Use Measures Data Source Air Compressor Demand Reduction 7th Plan Compressed Air Air Compressor Equipment 7th Plan Air Compressor Optimization 7th Plan Efficient Centrifugal Fan 7th Plan Fan Energy Management 7th Plan Fans Fan Equipment Upgrade 7th Plan Fan System Optimization 7th Plan Paper: Premium Fan 7th Plan Efficient Lighting Shift 7th Plan Lighting HighBay Lighting Shift 7th Plan Lighting Controls 7th Plan Motors Motors - Rewind 7th Plan Clean Room: Change Filter Strategy 7th Plan Clean Room: Chiller Optimize 7th Plan Clean Room: Clean Room HVAC 7th Plan Process: Electronic Mfg Elec Chip Fab: Eliminate Exhaust 7th Plan Elec Chip Fab: Exhaust Injector 7th Plan Elec Chip Fab: Reduce Gas Pressure 7th Plan Elec Chip Fab: Solidstate Chiller 7th Plan Energy Project Management 7th Plan Integrated Plant Energy Management 7th Plan Material Handling VFD 7th Plan Process: General Material Handling 7th Plan Panel: Hydraulic Press 7th Plan Plant Energy Management 7th Plan Synchronous Belts 7th Plan Process: Kraft Mfg Kraft: Efficient Agitator 7th Plan Mech Pulp: Premium Process 7th Plan Process: Mech Mfg Mech Pulp: Refiner Plate Improvement 7th Plan Mech Pulp: Refiner Replacement 7th Plan Process: Metal Mfg Metal: New Arc Furnace 7th Plan Process: Paper Mfg Paper: Efficient Pulp Screen 7th Plan

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End Use Measures Data Source

Paper: Large Material Handling 7th Plan

Paper: Material Handling 7th Plan Paper: Premium Control Large Material 7th Plan Process: Wood Mfg Wood: Replace Pneumatic Conveyor 7th Plan Kraft: Effluent Treatment System 7th Plan Pump Energy Management 7th Plan Pumps Pump Equipment Upgrade 7th Plan Pump System Optimization 7th Plan CA Retrofit -- CO2 Scrub 7th Plan CA Retrofit -- Membrane 7th Plan Cold Storage Retrofit 7th Plan Cold Storage Tuneup 7th Plan Food: Cooling and Storage 7th Plan Refrigerated Storage Food: Refrig Storage Tuneup 7th Plan Fruit Storage Refer Retrofit 7th Plan Fruit Storage Tuneup 7th Plan Groc Dist Retrofit 7th Plan Groc Dist Tuneup 7th Plan Transformers Transformers 7th Plan

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Table A-7 Distribution Efficiency End Uses and Measures

End Use Measures Data Source LDC Voltage Control Method 7th Plan Minor System Improvements 7th Plan

Utility Distribution System Major System Improvements 7th Plan EOL Voltage Control Method 7th Plan SCL Implement EOL w/ Major System 7th Plan Improvements

Table A-8 Other End Uses and Measures

End Use Measures Data Source Water & Municipal Sewage Treatment 7th Plan Wastewater Municipal Water Supply System Measure Suite 7th Plan Traffic Street and Roadway Lighting 7th Plan

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Appendix VII – Energy Efficiency Potential by End-Use

Residential aMW 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 Lighting 0.56 0.59 0.60 0.62 0.64 0.61 0.59 0.56 0.53 0.50 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 HP / DHP 0.29 0.30 0.31 0.32 0.33 0.32 0.30 0.29 0.27 0.26 0.32 0.32 0.32 0.32 0.32 0.32 0.32 0.32 0.32 0.32 Envelope Retro 0.14 0.14 0.15 0.15 0.16 0.15 0.14 0.14 0.13 0.12 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 0.35 Water Heat 0.40 0.42 0.44 0.45 0.46 0.44 0.42 0.40 0.38 0.36 0.27 0.27 0.27 0.27 0.27 0.27 0.27 0.27 0.27 0.27 Consumer Electronics 0.53 0.56 0.58 0.60 0.61 0.59 0.56 0.53 0.51 0.48 0.66 0.66 0.66 0.66 0.66 0.66 0.66 0.66 0.66 0.66 Appliances 0.11 0.12 0.12 0.12 0.13 0.12 0.12 0.11 0.11 0.10 0.09 0.09 0.09 0.09 0.09 0.09 0.09 0.09 0.09 0.09 Envelope New 0.12 0.13 0.13 0.14 0.14 0.13 0.13 0.12 0.11 0.11 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 Cooling 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Total 2.15 2.26 2.33 2.40 2.47 2.37 2.26 2.15 2.04 1.94 1.96 1.96 1.96 1.96 1.96 1.96 1.96 1.96 1.96 1.96

Commercial aMW 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 Lighting 0.23 0.28 0.30 0.32 0.32 0.30 0.28 0.25 0.23 0.21 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 PC Network/Supply 0.04 0.04 0.06 0.06 0.06 0.06 0.06 0.04 0.04 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 HVAC Controls 0.13 0.16 0.19 0.21 0.21 0.21 0.21 0.21 0.19 0.16 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 0.22 Refrigeration 0.18 0.18 0.18 0.18 0.16 0.16 0.16 0.14 0.13 0.11 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 Exterior Lighting 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 Rooftop Units 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Envelope 0.09 0.09 0.09 0.09 0.09 0.09 0.09 0.09 0.08 0.08 0.11 0.11 0.11 0.11 0.11 0.11 0.11 0.11 0.11 0.11 Ventilation 0.07 0.07 0.07 0.08 0.08 0.08 0.08 0.08 0.08 0.08 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 0.04 Food Preparation 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 Chillers 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Street/Roadway Lighting 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 Data Centers 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Water Heat 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 HP / DHP 0.13 0.13 0.13 0.13 0.13 0.13 0.11 0.11 0.10 0.07 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 Motors 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Compressed Air 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 Total 0.96 1.04 1.11 1.17 1.15 1.12 1.08 1.03 0.92 0.81 0.61 0.61 0.61 0.61 0.61 0.61 0.61 0.61 0.61 0.61

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Industrial aMW 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 Compressed Air 0.01 0.01 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Fans 0.01 0.02 0.02 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.02 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Lighting 0.09 0.07 0.05 0.04 0.03 0.03 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 Motors 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Process: Electronic Mfg 0.28 0.28 0.29 0.29 0.29 0.27 0.22 0.18 0.15 0.12 0.10 0.08 0.06 0.04 0.03 0.03 0.00 0.00 0.00 0.00 Process: General 0.10 0.08 0.07 0.06 0.06 0.06 0.06 0.06 0.06 0.05 0.04 0.03 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 Process: Paper Mfg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Process: Wood Mfg 0.00 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Pumps 0.02 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.03 0.02 0.02 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 Water & Wastewater 0.09 0.09 0.09 0.09 0.08 0.08 0.07 0.06 0.04 0.03 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 0.05 Refrigerated Storage 0.02 0.02 0.02 0.02 0.02 0.01 0.01 0.01 0.01 0.01 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Total 0.63 0.59 0.57 0.57 0.56 0.54 0.48 0.42 0.35 0.29 0.26 0.21 0.17 0.14 0.11 0.10 0.07 0.07 0.06 0.06

Distribution Efficiency aMW 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 Reduce system voltage 0.02 0.03 0.04 0.05 0.06 0.07 0.08 0.08 0.09 0.09 0.10 0.10 0.10 0.10 0.11 0.11 0.11 0.11 0.11 0.11 Minor system improvements 0.01 0.02 0.02 0.03 0.04 0.04 0.05 0.05 0.05 0.06 0.06 0.06 0.06 0.06 0.06 0.06 0.06 0.06 0.06 0.06 Major system improvements 0.01 0.02 0.02 0.03 0.04 0.05 0.05 0.05 0.06 0.06 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 0.07 EOL voltage control method 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Total 0.04 0.06 0.09 0.12 0.14 0.16 0.18 0.19 0.20 0.21 0.22 0.24 0.24 0.24 0.24 0.24 0.24 0.24 0.24 0.24

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Appendix VIII – Measure Detail

Column Heading Definitions

 Sector – Customer sector: Residential, Commercial, Industrial, or Distribution Efficiency  End-Use – Highest level measure category  Measure Name – Measure name as defined by the Sixth and/or Seventh Power Plans  Measure Life – Assumed life of the measure, in years  Initial Capital Cost – The incremental capital cost of the measure. It is the initial cost associated with the savings value  Bulk Energy (kWh/unit) – Energy savings of the measure at the bulk system level (busbar), including line losses.  Wholesale demand (kW) – Measure demand savings coincident with the wholesale power system annual peak  Retail demand (kW) – Non-coincident regional peak demand savings of the measure  TRC Levelized Cost ($/MWh) – Total Resource Cost (TRC) levelized costs include the same components as the TRC benefit/cost ratio. All costs minus all benefits regardless of which sponsor incurs the cost or accrues the benefit. Benefits are subtracted from costs and then levelized over the life of the program.  Total Sponsor Levelized Cost ($/MWh) – This levelized cost includes the capital, maintenance, and administrative costs of the measure. It does not include any adjustment for benefits. Costs are levelized over the life of the program.  Total B/C Ratio – The benefit cost ratio based on the Total Resource Cost test. It includes the present value of all benefits divided by the present value of all costs.

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TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) CEE Tier 1 Clothes Washer - Any DHW, Residential Appliances Any Dryer - 54% ENERGY STAR Baseline 14 $114.06 -$82.89 $237.09 1.51 53.39 0.00 0.03 CEE Tier 2 Clothes Washer - Any DHW, Residential Appliances Any Dryer - 54% ENERGY STAR Baseline 14 $158.85 -$91.72 $207.39 1.63 85.01 0.00 0.04 Energy Star Dishwasher (valid after Residential Appliances May 2013) - Any DHW 15 $5.28 -$6.75 $291.99 1.16 1.92 0.00 0.00 Residential Appliances Compact Freezer - Energy Star 7 $11.67 $178.29 $225.98 0.38 11.62 0.00 0.00 Residential Appliances Standard Size Freezer - Energy Star 22 $40.82 $82.43 $130.12 0.66 26.68 0.00 0.01 Residential Appliances Heat Pump Dryer 16 $271.00 $88.12 $142.99 0.66 193.26 0.00 0.09 Residential Appliances Microwave Oven 11 $4.07 -$12.02 $58.27 1.88 9.14 0.00 0.01 Residential Appliances Non Self-Cleaning Oven 20 $144.10 $199.37 $269.67 0.41 47.83 0.00 0.05 Residential Appliances Self-Cleaning Oven 20 $143.96 $182.00 $252.30 0.43 51.08 0.00 0.05 Compact Refrigerator and Refrigerator- Residential Appliances freezer - Energy Star 5 $9.95 $170.49 $216.39 0.39 11.19 0.00 0.00 Standard Size Refrigerator and Residential Appliances Refrigerator-freezer - Energy Star 15 $90.51 $152.08 $197.98 0.42 48.54 0.00 0.01 Consumer Residential Electronics Infrared sensing advanced power strip 5 $58.70 $19.20 $53.18 1.35 268.51 0.02 0.03 Consumer Residential Electronics Load sensing advanced power strip 5 $29.34 $187.56 $221.55 0.32 32.22 0.00 0.00 Consumer Occupancy sensing advanced power Residential Electronics strip 5 $0.00 -$33.98 $0.00 9,999.00 42.96 0.00 0.00 Consumer Energy Star - Weighted Average Residential Electronics Commercial Monitor 4 $0.00 -$64.93 $0.00 9,999.00 33.27 0.02 0.02 Consumer Energy Star - Weighted Average Residential Electronics Residential Monitor 5 $7.23 -$2.84 $55.13 1.71 31.89 0.00 0.02 Consumer Energy Star - Weighted Average Residential Electronics Commercial Desktop 5 $0.00 -$70.42 $0.00 9,999.00 133.19 0.07 0.08 Consumer Energy Star - Weighted Average Residential Electronics Residential Desktop 5 $12.47 -$30.17 $44.43 2.53 68.27 0.03 0.06 Consumer Energy Star - Weighted Average Set Top Residential Electronics Boxes 5 $12.32 -$34.09 $16.94 5.27 176.91 0.04 0.04 Energy Star Window Air Conditioner Residential Cooling 8000 Btu/hr - Cooling Zone 1 9 $7.06 -$18.93 $41.17 2.36 25.97 0.00 0.02 New Manufactured Home Thermal Residential Envelope New Shell - ATTIC R38 - ATTIC R49 - Heating 20 $396.50 $26.74 $91.70 1.16 387.06 0.09 0.25

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TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Zone 1

New Manufactured Home Thermal Shell - FLOOR R33 - FLOOR R44 - Residential Envelope New Heating Zone 1 20 $308.39 $77.69 $142.64 0.74 193.53 0.05 0.12 New Manufactured Home Thermal Shell - VAULT R25 - VAULT R30 - Residential Envelope New Heating Zone 1 20 $176.22 -$32.35 $32.60 3.25 483.83 0.11 0.31 New Manufactured Home Thermal Shell - VAULT R30 - VAULT R38 - Residential Envelope New Heating Zone 1 20 $264.33 $16.56 $81.51 1.30 290.30 0.07 0.19 New Multifamily Thermal Shell - ATTIC R38 STD - ATTIC R49 ADVrh - Heating Residential Envelope New Zone 1 20 $152.10 $28.58 $93.54 1.13 145.56 0.03 0.09 New Multifamily Thermal Shell - SLAB R10-2FT - SLAB R10-4FT - Heating Zone Residential Envelope New 1 20 $107.10 $28.79 $93.75 1.13 102.27 0.02 0.07 New Multifamily Thermal Shell - SLAB R10-4FT - SLAB R10-FULL - Heating Residential Envelope New Zone 1 20 $217.45 $30.21 $95.17 1.11 204.54 0.05 0.13 New Multifamily Thermal Shell - WINDOW CL30 - WINDOW CL25 - Residential Envelope New Heating Zone 1 20 $342.00 $46.73 $111.69 0.95 274.11 0.06 0.18 New Single Family Thermal Shell - ATTIC R38 STD - ATTIC R49 ADVrh - Residential Envelope New Heating Zone 1 20 $633.71 $23.40 $88.36 1.20 642.02 0.15 0.41 New Single Family Thermal Shell - INFILTRATION @ 0.20 ACH w/HRV - Residential Envelope New Heating Zone 1 20 $1,146.92 -$10.01 $54.94 1.93 1,868.77 0.44 1.20 New Single Family Thermal Shell - SLAB R10-2FT - SLAB R10-4FT - Heating Zone Residential Envelope New 1 20 $358.90 $38.00 $102.95 1.03 312.05 0.07 0.20 New Single Family Thermal Shell - SLAB R10-4FT - SLAB R10-FULL - Heating Residential Envelope New Zone 1 20 $728.67 $39.56 $104.51 1.01 624.10 0.15 0.40 New Single Family Thermal Shell - WINDOW CL30 - WINDOW CL22 - Residential Envelope New Heating Zone 1 20 $832.20 $11.05 $76.00 1.39 980.21 0.23 0.63 Manufactured Home Weatherization - Insulate Attic - R-0 to R-22 - Heating Residential Envelope Retro Zone 1 (Average Heating System) 25 $541.64 $17.35 $68.29 1.36 632.87 0.14 0.34

Clark Public Utilities—Conservation Potential Assessment 80

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Manufactured Home Weatherization - Insulate Attic - R-11 to R-30 - Heating Residential Envelope Retro Zone 1 (Average Heating System) 25 $541.64 $300.18 $351.12 0.26 123.08 0.03 0.07 Manufactured Home Weatherization - Insulate Floors - R-0 to R-22 - Heating Residential Envelope Retro Zone 1 (Average Heating System) 25 $1,357.81 $156.49 $207.43 0.45 522.28 0.11 0.28 Manufactured Home Weatherization - Insulate Floors - R-11 to R-22 - Heating Residential Envelope Retro Zone 1 (Average Heating System) 25 $1,264.27 $407.92 $458.85 0.20 219.84 0.05 0.12 Manufactured Home Weatherization - Windows - Double Pane to Class 30 - Heating Zone 1 (Average Heating Residential Envelope Retro System) 25 $2,187.36 $346.70 $397.64 0.23 438.90 0.10 0.24 Manufactured Home Weatherization - Windows - Single Pane to Class 30 - Heating Zone 1 (Average Heating Residential Envelope Retro System) 25 $2,187.36 $105.79 $156.72 0.59 1,113.58 0.24 0.61 Multi Family Weatherization - Insulate Walls - R-0 to R-11 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $455.54 -$9.79 $41.15 2.26 706.11 0.15 0.38 Multi Family Weatherization - Windows - Double Pane to Class 30 - Heating Residential Envelope Retro Zone 1 (Average Heating System) 45 $2,799.43 $23.93 $74.87 1.24 2,384.73 0.52 1.30 Multi Family Weatherization - Windows - Single Pane to Class 30 - Heating Zone Residential Envelope Retro 1 (Average Heating System) 45 $2,799.43 -$9.37 $41.57 2.23 4,294.94 0.94 2.33 Multifamily Weatherization - ATTIC R0 - R19 (Cost and Savings per square foot Residential Envelope Retro of component) - Heating Zone 1 45 $201.90 $9.28 $60.22 1.54 213.84 0.05 0.12 Multifamily Weatherization - ATTIC R19 - R30 (Cost and Savings per square foot Residential Envelope Retro of component) - Heating Zone 1 45 $174.28 $147.21 $198.15 0.47 56.09 0.01 0.03 Multifamily Weatherization - FLOOR R0 - R19 (Cost and Savings per square foot Residential Envelope Retro of component) - Heating Zone 1 45 $323.41 $30.67 $81.60 1.14 252.76 0.06 0.14 Single Family Weatherization - FLOOR R0 - FLOOR R19(Cost and Savings per square foot of component) - Heating Residential Envelope Retro Zone 1 45 $1,747.83 $53.83 $104.77 0.89 1,063.99 0.23 0.58

Clark Public Utilities—Conservation Potential Assessment 81

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Single Family Weatherization - Insulate Attic - R-0 to R-38 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $1,385.72 -$22.21 $28.73 3.23 3,076.21 0.67 1.67 Single Family Weatherization - Insulate Attic - R-0 to R-49 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $1,583.68 -$18.57 $32.37 2.87 3,120.61 0.68 1.70 Single Family Weatherization - Insulate Attic - R-19 to R-38 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $1,046.36 $173.87 $224.81 0.41 296.85 0.06 0.16 Single Family Weatherization - Insulate Attic - R-19 to R-49 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $1,244.32 $171.72 $222.65 0.42 356.42 0.08 0.19 Single Family Weatherization - Insulate Walls - R-0 to R-11 - Heating Zone 1 Residential Envelope Retro (Average Heating System) 45 $1,544.29 $0.14 $51.08 1.82 1,928.26 0.42 1.05 Single Family Weatherization - Windows - Double Pane to Class 30 - Heating Zone 1 (Average Heating Residential Envelope Retro System) 25 $4,127.73 $214.08 $265.01 0.35 1,242.72 0.27 0.68 Single Family Weatherization - Windows - Single Pane to Class 30 - Heating Zone 1 (Average Heating Residential Envelope Retro System) 25 $4,127.73 $83.04 $133.98 0.69 2,458.18 0.54 1.34 Install Ductless Heat Pump in House with Existing FAF - Manufactured Home Residential HP / DHP - HZ1 15 $3,606.24 -$10.17 $62.17 1.83 6,158.78 1.58 4.45 Existing Manufactured Home HVAC Conversion - Convert Electric FAF w/CAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $5,999.98 $13.72 $81.64 1.34 6,578.93 1.67 4.75 Existing Manufactured Home HVAC Conversion - Convert Electric FAF w/oCAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $5,999.98 $18.68 $87.12 1.27 6,164.68 1.67 4.47

Clark Public Utilities—Conservation Potential Assessment 82

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Existing Manufactured Home HVAC Upgrade - Updgrade to HSPF 9.0/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $1,621.00 $228.34 $296.35 0.37 489.64 0.13 0.35 Existing Single Family DHP - Convert Electric Baseboard Heat to HSPF 7.7/SEER 13 Ductless Heat Pump - Single Zone - Heating Zone 1 - Cooling Residential HP / DHP Zone 1 20 $3,407.00 $71.23 $128.64 0.77 2,370.80 0.62 1.71 Install Ductless Heat Pump in House with Existing FAF - Single Family Home - Residential HP / DHP HZ1 15 $3,606.24 $2.65 $92.96 1.42 4,118.65 1.06 2.98 Existing Single Family HVAC Conversion - Convert Electric FAF w/CAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Residential HP / DHP Zone 1 - Cooling Zone 1 20 $6,097.80 $26.50 $94.43 1.16 5,780.23 1.47 4.17 Existing Single Family HVAC Conversion - Convert Electric FAF w/oCAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Residential HP / DHP Zone 1 - Cooling Zone 1 20 $6,097.80 $31.64 $100.03 1.10 5,456.68 1.47 3.96

Existing Single Family Home HVAC Upgrade - Central Heat Pump Upgrade to Variable Capacity Central Heat Pump Residential HP / DHP - Heating Zone 1 - Cooling Zone 1 15 $5,356.85 $945.09 $1,011.81 0.11 562.10 0.13 0.40 Existing Single Family HVAC Upgrade - Updgrade to HSPF 9.0/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $63.00 -$39.46 $28.54 3.84 197.58 0.05 0.14 New SF HVAC Upgrade - Central Heat Pump Upgrade to Variable Capacity Residential HP / DHP Central Heat Pump 15 $4,919.69 $790.11 $866.26 0.13 602.97 0.12 0.43 New Manufactured Home HVAC Conversion - Convert Electric FAF w/CAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $5,999.98 $45.65 $113.57 0.96 4,729.27 1.20 3.41

Clark Public Utilities—Conservation Potential Assessment 83

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) New Manufactured Home HVAC Conversion - Convert Electric FAF w/oCAC to HSPF 8.5/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $5,999.98 $53.82 $122.35 0.90 4,389.78 1.20 3.19 New Manufactured Home HVAC Upgrade - Updgrade to HSPF 9.0/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $1,621.00 $228.34 $296.35 0.37 489.64 0.13 0.35 New Single Family DHP - Convert Electric Baseboard Heat to HSPF 7.7/SEER 13 Ductless Heat Pump - Single Zone - Heating Zone 1 - Cooling Residential HP / DHP Zone 1 20 $3,407.00 $46.80 $104.06 0.95 2,930.89 0.75 2.12

Existing Single Family Home HVAC Conversion - Convert FAF w/CAC to 12.0 HSPF/18 SEER Variable Speed Heat Residential HP / DHP Pump - Heating Zone 1 - Cooling Zone 1 20 $7,192.15 $33.52 $101.41 1.08 6,348.72 1.60 4.58

Existing Single Family Home HVAC Conversion - Convert FAF w/o CAC to 12.0 HSPF/18 SEER Variable Speed Heat Residential HP / DHP Pump - Heating Zone 1 - Cooling Zone 1 20 $8,608.11 $62.14 $130.63 0.84 5,899.00 1.60 4.28 New Single Family HVAC Conversion - Convert New Electric FAF w/CAC to HSPF 8.5/SEER 14 Heat Pump & w/Interior HVAC & PTCS Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $3,796.04 -$16.77 $51.16 2.14 6,642.55 1.69 4.80 New Single Family HVAC Conversion - Convert New Electric FAF w/oCAC to HSPF 8.5/SEER 14 Heat Pump & w/Interior HVAC & PTCS Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $5,729.05 $13.24 $81.61 1.35 6,284.15 1.69 4.56 New Single Family HVAC Upgrade - Updgrade to HSPF 9.0/SEER 14 Heat Pump & w/Interior HVAC & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $63.00 -$39.46 $28.54 3.84 197.58 0.05 0.14

Clark Public Utilities—Conservation Potential Assessment 84

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) New Single Family HVAC Upgrade - Upgrade to HSPF 9.0/SEER 14 Heat Pump & w/PTCS Duct Sealing & Commissioning - Heating Zone 1 - Residential HP / DHP Cooling Zone 1 20 $1,531.61 -$7.70 $60.13 1.82 2,280.25 0.57 1.64 Single Family WIFI Enabled Thermostat Residential HP / DHP - Heating Zone 1 10 $225.77 -$3.22 $54.07 1.83 585.04 0.15 0.42 Single Family WIFI Enabled Thermostat Residential HP / DHP - Heating Zone 2 10 $490.90 $60.55 $117.82 0.84 583.80 0.15 0.42 Single Family WIFI Enabled Thermostat Residential HP / DHP - Heating Zone 3 10 $467.42 $60.54 $117.84 0.84 555.82 0.14 0.40 Energy Star Lighting - Existing Dwelling Residential Lighting Unit LPD = 0.6 W/sq.ft. 12 $187.35 -$2.60 $47.47 1.86 495.07 0.04 0.14 Energy Star Lighting - New Dwelling Residential Lighting Unit LPD = 0.6 W/sq.ft. 12 $187.35 $42.22 $92.28 0.96 495.07 0.04 0.14 Customer-side Solar PV (1 KW System), Residential Solar PV Solar Zone 1, Winter peak load area 20 $4,126.27 $273.47 $313.42 0.26 1,298.45 0.00 0.01 Customer-side Solar PV (1 KW System), Residential Solar PV Solar Zone 2, Winter peak load area 20 $4,126.27 $273.47 $313.44 0.26 1,298.37 0.00 0.01 Customer-side Solar PV (1 KW System), Residential Solar PV Solar Zone 3, Winter peak load area 20 $4,126.27 $273.48 $313.45 0.26 1,298.32 0.00 0.01 Customer-side Solar PV (1 KW System), Residential Solar PV Solar Zone 4, Winter peak load area 20 $4,126.27 $273.49 $313.45 0.26 1,298.29 0.00 0.01 Customer-side Solar PV (1 KW System), Residential Solar PV Solar Zone 5, Winter peak load area 20 $4,126.27 $273.46 $313.45 0.26 1,298.29 0.00 0.01 Residential Solar WH SHW Solar Zone 1 20 $7,784.64 $632.91 $673.22 0.12 1,141.57 0.01 0.01 Residential Solar WH SHW Solar Zone 2 20 $7,784.64 $599.12 $639.56 0.13 1,201.67 0.01 0.02 Residential Solar WH SHW Solar Zone 3 20 $7,784.64 $554.17 $594.94 0.14 1,291.79 0.01 0.03 Residential Solar WH SHW Solar Zone 4 20 $7,784.64 $470.84 $511.78 0.16 1,501.69 0.01 0.04 Residential Solar WH SHW Solar Zone 5 20 $7,784.64 $441.60 $482.68 0.17 1,592.21 0.01 0.05 Residential Water Heat HPWH Single Family Tier1_buffered 13 $654.55 $13.25 $68.02 1.37 1,121.60 0.14 0.45 Residential Water Heat HPWH Single Family Tier1_indor2_efaf 13 $654.55 $4.05 $56.25 1.59 1,356.21 0.17 0.54 Residential Water Heat HPWH Single Family Tier1_indor2_hp85 13 $654.55 $3.48 $56.87 1.60 1,341.46 0.17 0.54 Residential Water Heat HPWH Single Family Tier1_indor2_zonl 13 $654.55 $3.77 $56.26 1.60 1,356.17 0.17 0.54

Clark Public Utilities—Conservation Potential Assessment 85

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Residential Water Heat HPWH Single Family Tier2_buffered 13 $1,069.11 $556.26 $611.03 0.15 203.94 0.03 0.08 Residential Water Heat HPWH Single Family Tier2_indor2_efaf 13 $1,069.11 $1,353.72 $1,401.68 0.07 88.90 0.01 0.04 Residential Water Heat HPWH Single Family Tier2_indor2_hp85 13 $1,069.11 $1,266.90 $1,317.75 0.07 94.56 0.01 0.04 Residential Water Heat HPWH Single Family Tier2_indor2_zonl 13 $1,069.11 $1,353.43 $1,402.15 0.07 88.87 0.01 0.04 Residential-type Water Heater (>= 45 Residential Water Heat gallons, <55 gallons_EF0.94+) 15 $68.91 -$0.26 $54.51 1.71 152.56 0.02 0.06 Showerhead Replacement in Residential Dwellings - Any Residential Water Heat Showerhead, Electric DHW 10 $24.00 -$102.03 $16.74 9.40 200.91 0.02 0.08 Single Family Bathroom Aerator 1.0 Residential Water Heat GPM AnyWH 15 $4.52 -$52.87 $6.63 14.79 72.27 0.01 0.03 Commercial Chillers Variable Speed Chiller-New-Hospital 30 $214.80 -$15.68 $20.68 3.79 876.73 0.00 0.25 Commercial Chillers Variable Speed Chiller-New-Large Off 30 $94.80 $9.40 $45.76 1.71 174.89 0.00 0.05 Commercial Chillers Variable Speed Chiller-New-Lodging 30 $28.32 $8.34 $44.71 1.75 53.48 0.00 0.02 Variable Speed Chiller-New-Medium Commercial Chillers Off 30 $6.32 $9.40 $45.76 1.71 11.66 0.00 0.00 Commercial Chillers Variable Speed Chiller-New-University 30 $37.92 $9.40 $45.76 1.71 69.96 0.00 0.02 Commercial Chillers Variable Speed Chiller-NR-Hospital 30 $153.03 -$18.62 $19.07 4.01 614.24 0.00 0.18 Commercial Chillers Variable Speed Chiller-NR-Large Off 30 $198.72 $4.43 $42.12 1.81 361.16 0.00 0.10 Commercial Chillers Variable Speed Chiller-NR-Lodging 30 $19.28 $3.61 $41.31 1.85 35.74 0.00 0.01 Commercial Chillers Variable Speed Chiller-NR-Medium Off 30 $11.93 $4.43 $42.12 1.81 21.69 0.00 0.01 Commercial Chillers Variable Speed Chiller-NR-University 30 $35.40 $4.45 $42.14 1.81 64.31 0.00 0.02 Commercial Compressed Air Compressed Air-NR-Anchor 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Assembly 10 $0.79 -$28.39 $16.31 5.07 7.37 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Big Box 10 $3.13 -$28.39 $16.31 5.07 29.09 0.00 0.00 Commercial Compressed Air Compressed Air-NR-High End 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Hospital 10 $0.45 -$28.39 $16.31 5.07 4.15 0.00 0.00 Commercial Compressed Air Compressed Air-NR-K-12 10 $0.33 -$28.39 $16.31 5.07 3.03 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Large Off 10 $9.93 -$28.39 $16.31 5.07 92.25 0.01 0.01 Commercial Compressed Air Compressed Air-NR-Lodging 10 $0.47 -$28.39 $16.31 5.07 4.33 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Medium Off 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00

Clark Public Utilities—Conservation Potential Assessment 86

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Compressed Air Compressed Air-NR-MIniMart 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Other 10 $1.96 -$28.39 $16.31 5.07 18.19 0.00 0.00 Commercial Compressed Air Compressed Air-NR-OtherHealth 10 $0.45 -$28.39 $16.31 5.07 4.15 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Restaurant 10 $1.13 -$28.39 $16.31 5.07 10.51 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Small Box 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Small Off 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Supermarket 10 $1.40 -$28.39 $16.31 5.07 12.98 0.00 0.00 Commercial Compressed Air Compressed Air-NR-University 10 $0.33 -$28.39 $16.31 5.07 3.03 0.00 0.00 Commercial Compressed Air Compressed Air-NR-Warehouse 10 $2.90 -$28.39 $16.31 5.07 26.97 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Anchor 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Assembly 10 $4.02 -$34.04 $10.66 7.75 114.58 0.01 0.01 Commercial Compressed Air Compressed Air-Retro-Big Box 10 $15.87 $10.55 $55.25 1.50 87.26 0.01 0.01 Commercial Compressed Air Compressed Air-Retro-High End 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Hospital 10 $2.26 $10.55 $55.25 1.50 12.45 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-K-12 10 $1.65 $10.55 $55.25 1.50 9.09 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Large Off 10 $50.33 $10.55 $55.25 1.50 276.75 0.02 0.03 Commercial Compressed Air Compressed Air-Retro-Lodging 10 $2.36 $10.55 $55.25 1.50 13.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Medium Off 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-MIniMart 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Other 10 $9.92 $10.55 $55.25 1.50 54.56 0.00 0.01 Commercial Compressed Air Compressed Air-Retro-OtherHealth 10 $2.26 $10.55 $55.25 1.50 12.45 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Restaurant 10 $5.74 $10.55 $55.25 1.50 31.54 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Small Box 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Small Off 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Supermarket 10 $7.08 $10.55 $55.25 1.50 38.93 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-University 10 $1.65 $10.55 $55.25 1.50 9.09 0.00 0.00 Commercial Compressed Air Compressed Air-Retro-Warehouse 10 $14.71 $10.55 $55.25 1.50 80.90 0.01 0.01 Commercial Data Centers Best Practice 5 $27.96 -$19.91 $15.71 4.72 480.39 0.05 0.07

Clark Public Utilities—Conservation Potential Assessment 87

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Data Centers Commercial Technology 8 $39.16 -$4.68 $30.95 2.39 221.85 0.02 0.03 Commercial Data Centers Cutting Edge 6 $5.66 -$10.25 $25.37 2.92 52.43 0.01 0.01 Commercial Envelope Roof Insulation-NR-Anchor 20 $41.59 -$36.04 $17.06 5.40 227.75 0.01 0.11 Commercial Envelope Roof Insulation-NR-Assembly 20 $611.10 -$34.65 $23.65 4.06 2,413.29 0.06 1.36 Commercial Envelope Roof Insulation-NR-Big Box 20 $41.52 -$43.89 $16.44 5.93 235.87 0.00 0.14 Commercial Envelope Roof Insulation-NR-High End 20 $141.78 -$46.59 $12.38 7.80 1,069.38 0.03 0.60 Commercial Envelope Roof Insulation-NR-Hospital 20 $404.74 -$44.19 $19.46 5.13 1,942.86 0.01 1.27 Commercial Envelope Roof Insulation-NR-K-12 20 $3.82 -$26.50 $36.63 2.71 9.73 0.00 0.01 Commercial Envelope Roof Insulation-NR-Large Off 20 $31.72 -$20.76 $29.26 3.07 101.26 0.01 0.04 Commercial Envelope Roof Insulation-NR-Lodging 20 $66.32 -$26.35 $23.80 3.78 260.33 0.02 0.11 Commercial Envelope Roof Insulation-NR-Medium Off 20 $34.97 -$22.35 $31.43 2.95 103.92 0.00 0.05 Commercial Envelope Roof Insulation-NR-MIniMart 20 $412.06 -$23.13 $32.99 2.83 1,166.78 0.02 0.68 Commercial Envelope Roof Insulation-NR-Other 20 $90.66 -$35.86 $22.36 4.29 378.72 0.01 0.21 Commercial Envelope Roof Insulation-NR-OtherHealth 20 $0.79 -$33.81 $18.36 4.98 4.02 0.00 0.00 Commercial Envelope Roof Insulation-NR-Restaurant 20 $205.37 -$7.10 $50.94 1.87 376.58 0.01 0.23 Commercial Envelope Roof Insulation-NR-Small Box 20 $118.16 -$44.88 $12.71 7.52 868.46 0.03 0.47 Commercial Envelope Roof Insulation-NR-Small Off 20 $69.94 -$22.35 $31.43 2.95 207.83 0.01 0.10 Commercial Envelope Roof Insulation-NR-Supermarket 20 $412.02 -$19.53 $34.56 2.66 1,113.44 0.03 0.60 Commercial Envelope Roof Insulation-NR-University 20 $116.38 -$34.94 $25.80 3.79 421.33 0.01 0.25 Commercial Envelope Roof Insulation-NR-Warehouse 20 $4.27 -$34.27 $28.28 3.52 14.09 0.00 0.01 SGSWindow-High-rise Office (VAV with Commercial Envelope Central Chillers / Wt. Boilers)-Portland 30 $31.61 $77.70 $125.04 0.70 19.35 0.00 0.00 SGSWindow-Mid-rise Office (Apackaged VAV with Wt. heating)- Commercial Envelope Portland 30 $31.61 $81.16 $131.68 0.69 18.38 0.00 0.00 SGSWindow-Small Office (AC with Wt. Commercial Envelope Furnace)-Portland 30 $31.61 $199.34 $241.88 0.34 10.00 0.00 0.00 Exterior Lighting: Façade - HID 150W - Commercial Ext Lighting New 16 $0.68 -$39.90 -$4.50 76.51 71.93 0.00 0.01 Exterior Lighting: Façade - HID 400W - Commercial Ext Lighting New 16 $0.84 -$36.58 -$1.17 26.17 31.04 0.00 0.01

Clark Public Utilities—Conservation Potential Assessment 88

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Exterior Lighting: Parking Lot - HPS Commercial Ext Lighting 250W - New 12 $13.13 -$25.67 $9.73 6.06 139.91 0.01 0.03 Exterior Lighting: Parking Lot - MH Commercial Ext Lighting 1000W - New 12 $0.95 -$17.98 $17.42 3.94 6.72 0.00 0.00 Exterior Lighting: Parking Lot - MH Commercial Ext Lighting 400W - New 12 $4.79 -$26.79 $8.61 6.57 55.24 0.00 0.01 Exterior Lighting: Walkway - CFL 26W - Commercial Ext Lighting New 7 $0.12 -$60.25 -$24.84 10.76 2.48 0.00 0.00 Exterior Lighting: Walkway - HID 150W Commercial Ext Lighting - New 16 $0.62 -$39.67 -$4.27 83.22 71.76 0.00 0.01 Exterior Lighting: Walkway - INC 75W - Commercial Ext Lighting New 7 $0.03 -$139.35 -$103.94 61.57 1.84 0.00 0.00 Exterior Lighting: Façade - HID 150W - Commercial Ext Lighting NR 16 $17.40 -$14.86 $20.54 2.99 71.93 0.00 0.01 Exterior Lighting: Façade - HID 400W - Commercial Ext Lighting NR 16 $5.39 -$20.78 $14.62 4.08 31.04 0.00 0.01 Exterior Lighting: Parking Lot - HPS Commercial Ext Lighting 250W - NR 12 $41.13 $0.73 $36.14 1.93 139.91 0.01 0.03 Exterior Lighting: Parking Lot - MH Commercial Ext Lighting 1000W - NR 12 $1.76 -$2.12 $33.29 2.13 6.72 0.00 0.00 Exterior Lighting: Parking Lot - MH Commercial Ext Lighting 400W - NR 12 $12.09 -$9.36 $26.04 2.60 55.24 0.00 0.01 Exterior Lighting: Walkway - CFL 26W - Commercial Ext Lighting NR 7 $0.12 -$60.25 -$24.84 10.76 2.48 0.00 0.00 Exterior Lighting: Walkway - HID 150W Commercial Ext Lighting - NR 14 $14.36 -$16.76 $18.65 3.25 70.91 0.00 0.01 Exterior Lighting: Walkway - INC 75W - Commercial Ext Lighting NR 7 $0.03 -$139.35 -$103.94 61.57 1.84 0.00 0.00 Commercial Ext Lighting LEC Exit Sign-Double-New 15 $47.41 -$18.64 $15.35 1.68 64.07 0.00 0.01 Commercial Ext Lighting LEC Exit Sign-Double-NR 15 $47.41 -$18.64 $15.35 1.68 64.07 0.00 0.01 Commercial Ext Lighting LEC Exit Sign-Single-New 15 $47.41 -$3.19 $30.79 1.25 31.93 0.00 0.00 Commercial Ext Lighting LEC Exit Sign-Single-NR 15 $47.41 -$3.19 $30.79 1.25 31.93 0.00 0.00 NR_PARKING_GARAGE_FIX_REPL_from Commercial Ext Lighting MH to BI-LEVEL_LED_FIX 9 $317.73 -$6.29 $27.70 2.39 1,637.79 0.12 0.19 Commercial Food Preparation Combi Oven (Wt Average) 10 $939.40 -$45.03 $8.67 10.50 16,411.69 0.74 2.77 Commercial Food Preparation Convection Oven (Wt Average) 10 $834.20 $35.55 $70.53 1.03 1,792.01 0.08 0.30 Commercial Food Preparation HFHC (Wt Average Size) 20 $602.51 $46.56 $81.54 0.89 690.18 0.03 0.12 Commercial Food Preparation Steamer (Wt Average Size) 9 $736.61 -$65.85 $2.71 39.08 44,722.57 2.03 7.54

Clark Public Utilities—Conservation Potential Assessment 89

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Food Preparation DCV Hood 5 hp 18 $7,500.00 $35.81 $74.70 1.05 10,012.56 1.11 2.40 Commercial Food Preparation DCV Hood w/ MUA 5 hp 18 $7,500.00 $2.60 $41.50 1.90 18,022.61 2.00 4.31 Commercial Food Preparation Pre-Rinse Spray Valve_0.61_to_0.8gpm 4 $126.70 -$140.06 $469.29 1.38 88.94 0.01 0.03 Commercial Food Preparation Pre-Rinse Spray Valve_0.81_to_1.0gpm 4 $126.70 -$315.85 $293.50 2.21 142.21 0.02 0.05 Commercial HP / DHP DHP-Retro-Anchor 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Assembly 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Big Box 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-High End 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Hospital 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-K-12 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Large Off 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Lodging 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Medium Off 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-MIniMart 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Other 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-OtherHealth 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Restaurant 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Small Box 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Small Off 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Supermarket 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-University 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Commercial HP / DHP DHP-Retro-Warehouse 20 $3,452.54 $14.82 $75.11 1.39 4,293.29 0.35 4.05 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Anchor 15 $19.04 $37.57 $75.29 1.03 28.46 0.00 0.01 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Assembly 15 $162.40 -$13.59 $24.13 3.22 757.37 0.08 0.15 Advanced Rooftop Controller-Retro-Big Commercial HVAC Controls Box 15 $163.61 -$19.40 $18.31 4.24 1,005.33 0.11 0.21 Advanced Rooftop Controller-Retro- Commercial HVAC Controls High End 15 $104.82 -$9.89 $27.82 2.79 423.90 0.05 0.09 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Hospital 15 $55.87 $13.73 $51.44 1.51 122.21 0.01 0.02

Clark Public Utilities—Conservation Potential Assessment 90

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Advanced Rooftop Controller-Retro-K- Commercial HVAC Controls 12 15 $85.39 $46.63 $84.34 0.92 113.92 0.01 0.02 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Large Off 15 $78.53 $33.82 $71.53 1.09 123.53 0.01 0.03 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Lodging 15 $55.87 $13.73 $51.44 1.51 122.21 0.01 0.02 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Medium Off 15 $285.42 $39.74 $77.46 1.00 414.63 0.04 0.08 Advanced Rooftop Controller-Retro- Commercial HVAC Controls MIniMart 15 $263.95 -$7.62 $30.09 2.58 986.94 0.10 0.20 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Other 15 $60.25 $7.00 $44.72 1.74 151.61 0.02 0.03 Advanced Rooftop Controller-Retro- Commercial HVAC Controls OtherHealth 15 $194.16 -$8.88 $28.83 2.69 757.74 0.08 0.15 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Restaurant 15 $661.30 -$3.17 $34.55 2.25 2,153.91 0.23 0.44 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Small Box 15 $165.80 -$22.60 $15.12 5.14 1,234.27 0.13 0.25 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Small Off 15 $180.60 $33.70 $71.42 1.09 284.56 0.03 0.06 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Supermarket 15 $263.95 -$7.62 $30.09 2.58 986.94 0.10 0.20 Advanced Rooftop Controller-Retro- Commercial HVAC Controls University 15 $85.39 $46.63 $84.34 0.92 113.92 0.01 0.02 Advanced Rooftop Controller-Retro- Commercial HVAC Controls Warehouse 15 $34.12 $39.24 $76.95 1.01 49.89 0.01 0.01 Commercial HVAC Controls Commercial EM-Retro-Anchor 5 $23.00 -$5.98 $40.00 2.14 155.19 0.02 0.03 Commercial HVAC Controls Commercial EM-Retro-Assembly 5 $38.20 -$1.18 $58.97 1.69 174.88 0.02 0.04 Commercial HVAC Controls Commercial EM-Retro-Big Box 5 $8.88 $10.20 $71.64 1.41 33.45 0.00 0.01 Commercial HVAC Controls Commercial EM-Retro-High End 5 $13.89 $49.24 $100.21 0.91 37.42 0.00 0.01 Commercial HVAC Controls Commercial EM-Retro-Hospital 5 $214.90 -$19.42 $35.38 2.65 1,639.79 0.11 0.35 Commercial HVAC Controls Commercial EM-Retro-K-12 5 $74.32 $35.86 $100.88 1.03 198.91 0.02 0.04 Commercial HVAC Controls Commercial EM-Retro-Large Off 5 $142.79 $5.46 $53.19 1.65 724.84 0.07 0.16 Commercial HVAC Controls Commercial EM-Retro-Lodging 5 $17.98 $1.80 $41.60 1.85 116.72 0.00 0.02 Commercial HVAC Controls Commercial EM-Retro-Medium Off 5 $21.30 $14.75 $63.79 1.39 90.13 0.01 0.02 Commercial HVAC Controls Commercial EM-Retro-MIniMart 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial HVAC Controls Commercial EM-Retro-Other 5 $45.44 -$11.36 $56.53 1.89 217.03 0.02 0.05

Clark Public Utilities—Conservation Potential Assessment 91

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial HVAC Controls Commercial EM-Retro-OtherHealth 5 $19.20 -$8.51 $34.02 2.25 152.32 0.00 0.03 Commercial HVAC Controls Commercial EM-Retro-Restaurant 5 $11.85 $14.97 $64.99 1.35 49.22 0.00 0.01 Commercial HVAC Controls Commercial EM-Retro-Small Box 5 $129.82 $86.48 $148.23 0.69 236.45 0.03 0.05 Commercial HVAC Controls Commercial EM-Retro-Small Off 5 $14.61 $114.98 $159.74 0.52 24.69 0.00 0.01 Commercial HVAC Controls Commercial EM-Retro-Supermarket 5 $12.33 -$4.15 $50.19 1.86 66.32 0.01 0.01 Commercial HVAC Controls Commercial EM-Retro-University 5 $195.80 $7.59 $60.40 1.52 875.27 0.07 0.18 Commercial HVAC Controls Commercial EM-Retro-Warehouse 5 $13.18 $26.68 $122.70 1.11 29.00 0.00 0.01 NR_LFStairwell3600_Fix_Repl_from Commercial Lighting LF_2019 to LF_Bi-Level_Fix 16 $1,931.83 $108.78 $156.88 0.56 1,416.70 0.15 0.27 NR_LFStairwell8760_Fix_Repl_from Commercial Lighting LF_2018 to LF_Bi-Level_Fix 16 $1,931.83 $26.33 $74.43 1.18 3,447.30 0.37 0.67 Lighting Controls Interior-New-Anchor- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Anchor- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Assembly-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Assembly-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Big Box- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Big Box- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-High Commercial Lighting End-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-High Commercial Lighting End-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Hospital-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Hospital-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-K-12- Commercial Lighting Integrated 15 $508.22 $111.77 $125.00 0.52 457.52 0.03 0.10 Lighting Controls Interior-New-K-12- Commercial Lighting Unitary 15 $308.01 $119.83 $118.66 0.49 292.09 0.02 0.06 Lighting Controls Interior-New-Large Commercial Lighting Off-Integrated 15 $508.22 $56.96 $88.05 0.83 649.48 0.04 0.15

Clark Public Utilities—Conservation Potential Assessment 92

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Lighting Controls Interior-New-Large Commercial Lighting Off-Unitary 15 $308.01 $47.36 $75.73 0.92 457.67 0.03 0.10 Lighting Controls Interior-New-Lodging- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Lodging- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Medium Commercial Lighting Off-Integrated 15 $508.22 $85.43 $103.18 0.64 554.27 0.04 0.13 Lighting Controls Interior-New-Medium Commercial Lighting Off-Unitary 15 $308.01 $58.18 $85.38 0.82 405.93 0.03 0.09 Lighting Controls Interior-New- Commercial Lighting MIniMart-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting MIniMart-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting OtherHealth-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting OtherHealth-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Other- Commercial Lighting Integrated 15 $508.22 $70.67 $100.61 0.71 568.44 0.05 0.12 Lighting Controls Interior-New-Other- Commercial Lighting Unitary 15 $308.01 $59.70 $86.53 0.79 400.56 0.03 0.08 Lighting Controls Interior-New- Commercial Lighting Restaurant-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Restaurant-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Small Commercial Lighting Box-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Small Commercial Lighting Box-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New-Small Commercial Lighting Off-Integrated 15 $508.22 $88.18 $111.13 0.61 514.61 0.05 0.12 Lighting Controls Interior-New-Small Commercial Lighting Off-Unitary 15 $308.01 $77.26 $87.47 0.66 396.24 0.04 0.09 Lighting Controls Interior-New- Commercial Lighting Supermarket-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-New- Commercial Lighting Supermarket-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00

Clark Public Utilities—Conservation Potential Assessment 93

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Lighting Controls Interior-New- Commercial Lighting University-Integrated 15 $508.22 $158.49 $168.82 0.40 338.75 0.03 0.07 Lighting Controls Interior-New- Commercial Lighting University-Unitary 15 $308.01 $102.43 $106.06 0.56 326.80 0.02 0.07 Lighting Controls Interior-New- Commercial Lighting Warehouse-Integrated 15 $332.82 $120.00 $139.51 0.49 268.45 0.03 0.07 Lighting Controls Interior-New- Commercial Lighting Warehouse-Unitary 15 $143.56 $135.34 $111.23 0.45 145.24 0.01 0.04 Lighting Controls Interior-NR-Anchor- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Anchor- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Assembly- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Assembly- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Big Box- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Big Box- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-High End- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-High End- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Hospital- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Hospital- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-K-12- Commercial Lighting Integrated 15 $508.22 $130.04 $139.85 0.46 408.93 0.03 0.09 Lighting Controls Interior-NR-K-12- Commercial Lighting Unitary 15 $308.01 $119.83 $118.66 0.49 292.09 0.02 0.06 Lighting Controls Interior-NR-Large Off- Commercial Lighting Integrated 15 $508.22 $58.25 $89.26 0.82 640.73 0.04 0.15 Lighting Controls Interior-NR-Large Off- Commercial Lighting Unitary 15 $308.01 $47.36 $75.73 0.92 457.67 0.03 0.10 Lighting Controls Interior-NR-Lodging- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Lodging- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00

Clark Public Utilities—Conservation Potential Assessment 94

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Lighting Controls Interior-NR-Medium Commercial Lighting Off-Integrated 15 $508.22 $70.47 $100.63 0.73 568.30 0.04 0.13 Lighting Controls Interior-NR-Medium Commercial Lighting Off-Unitary 15 $308.01 $58.18 $85.38 0.82 405.93 0.03 0.09 Lighting Controls Interior-NR-MIniMart- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-MIniMart- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR- Commercial Lighting OtherHealth-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR- Commercial Lighting OtherHealth-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Other- Commercial Lighting Integrated 15 $508.22 $72.15 $101.98 0.70 560.79 0.05 0.12 Lighting Controls Interior-NR-Other- Commercial Lighting Unitary 15 $308.01 $59.70 $86.53 0.79 400.56 0.03 0.08 Lighting Controls Interior-NR- Commercial Lighting Restaurant-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR- Commercial Lighting Restaurant-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Small Box- Commercial Lighting Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Small Box- Commercial Lighting Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR-Small Off- Commercial Lighting Integrated 15 $508.22 $84.96 $103.09 0.62 554.73 0.05 0.13 Lighting Controls Interior-NR-Small Off- Commercial Lighting Unitary 15 $308.01 $77.26 $87.47 0.66 396.24 0.04 0.09 Lighting Controls Interior-NR- Commercial Lighting Supermarket-Integrated 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR- Commercial Lighting Supermarket-Unitary 15 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Lighting Controls Interior-NR- Commercial Lighting University-Integrated 15 $508.22 $111.77 $125.00 0.52 457.52 0.03 0.10 Lighting Controls Interior-NR- Commercial Lighting University-Unitary 15 $308.01 $102.43 $106.06 0.56 326.80 0.02 0.07 Lighting Controls Interior-NR- Commercial Lighting Warehouse-Integrated 15 $332.82 $201.81 $193.39 0.32 193.66 0.02 0.05 Lighting Controls Interior-NR- Commercial Lighting Warehouse-Unitary 15 $143.56 $135.34 $111.23 0.45 145.24 0.01 0.04

Clark Public Utilities—Conservation Potential Assessment 95

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Market Average HP Low Power T8 Shift Commercial Lighting Large Off 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Medium Off 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Small Off 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Big Box 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Small Box 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting High End 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Anchor 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting K-12 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting University 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Warehouse 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Supermarket 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting MIniMart 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Restaurant 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Lodging 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Hospital 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting OtherHealth 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Assembly 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 Market Average HP Low Power T8 Shift Commercial Lighting Other 7 $0.81 -$14.26 $23.13 3.33 6.59 0.00 0.00 All Btype_New_CAN_FIX_REPL_from Commercial Lighting CFL to LED_FIX_KIT 14 $33.36 -$51.92 -$9.04 3.45 123.72 0.01 0.03 All Btype_New_CAN_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 13 $1.59 -$107.53 -$64.99 21.55 94.91 0.01 0.02

Clark Public Utilities—Conservation Potential Assessment 96

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) All Btype_New_DISP_FIX_REPL_from Commercial Lighting CFL to LED_FIX_KIT 10 $94.78 $98.94 $141.82 0.87 33.67 0.00 0.01 All Btype_New_DISP_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 8 $7.50 -$69.27 -$27.75 2.95 26.64 0.00 0.01 All Btype_New_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LED_FIX_KIT 21 $20.81 -$15.89 $28.24 2.45 56.23 0.00 0.01 All Btype_New_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LF2018 20 $2.34 -$26.86 $17.27 3.07 7.82 0.00 0.00 All Btype_New_HIGHBAY_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 19 $46.42 -$19.91 $24.32 2.28 104.41 0.01 0.02 All Btype_New_LF_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 16 $429.17 $3.54 $47.15 1.51 702.39 0.05 0.15 All Btype_NR_CAN_FIX_REPL_from CFL Commercial Lighting to LED_FIX_KIT 14 $18.40 -$52.48 -$8.92 3.40 64.47 0.01 0.01 All Btype_NR_CAN_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 13 $1.02 -$110.87 -$68.53 21.09 59.10 0.00 0.01 All Btype_NR_DISP_FIX_REPL_from CFL Commercial Lighting to LED_FIX_KIT 10 $55.74 $98.07 $141.63 0.87 18.72 0.00 0.00 All Btype_NR_DISP_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 9 $13.70 -$70.87 -$28.19 2.98 46.15 0.00 0.01 All Btype_NR_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LED_FIX_KIT 21 $27.14 -$15.55 $26.79 2.44 76.67 0.01 0.02 All Btype_NR_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LF2018 0 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 All Btype_NR_HIGHBAY_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 20 $36.56 -$18.70 $22.98 2.25 85.95 0.01 0.02 All Btype_NR_LF_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 16 $166.40 $4.86 $47.83 1.48 264.62 0.02 0.06 All Btype_NR_LF_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT_RDX 16 $22.98 -$29.64 $13.34 3.09 88.29 0.01 0.02 All Btype_NR_LF_FIX_REPL_from Commercial Lighting LF2018 to LF_FIX_KIT_RDX 20 $22.36 -$33.54 $9.43 2.78 58.57 0.00 0.01 All Btype_NR_LF_FIX_REPL_from Commercial Lighting LF2018 to TLED_PIN 14 $64.02 -$13.17 $29.80 1.76 120.46 0.01 0.03

Clark Public Utilities—Conservation Potential Assessment 97

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) All Btype_NR_LF_FIX_REPL_from Commercial Lighting LF2018 to TLED_PIN_RDX 14 $13.81 -$38.70 $4.27 3.61 67.49 0.01 0.01 All Btype_Retro_CAN_FIX_REPL_from Commercial Lighting CFL to LED_FIX_KIT 14 $64.84 $32.52 $76.07 1.05 64.47 0.01 0.01 All Btype_Retro_CAN_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 13 $10.71 -$90.49 -$48.15 5.65 59.10 0.00 0.01 All Btype_Retro_CAN_LAMP_REPL_from Commercial Lighting CFL to LED_CAN_LAMP 14 $26.80 -$36.72 $6.83 2.35 60.98 0.00 0.01 All Btype_Retro_CAN_LAMP_REPL_from Commercial Lighting INC_HAL to LED_CAN_LAMP 13 $4.43 -$104.34 -$62.00 10.74 58.49 0.00 0.01 All Btype_Retro_DISP_FIX_REPL_from Commercial Lighting CFL to LED_FIX_KIT 10 $111.81 $558.45 $602.00 0.44 18.72 0.00 0.00 All Btype_Retro_DISP_FIX_REPL_from Commercial Lighting INC_HAL to LED_FIX_KIT 9 $25.43 -$27.98 $14.70 1.68 46.15 0.00 0.01 All Btype_Retro_DISP_LAMP_REPL_from Commercial Lighting CFL to LED_PAR_MR 10 $51.02 $43.39 $86.94 0.99 22.13 0.00 0.00 All Btype_Retro_DISP_LAMP_REPL_from Commercial Lighting HID_CMH to LED_PAR_MR 0 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 All Btype_Retro_DISP_LAMP_REPL_from Commercial Lighting INC_HAL to HID_CMH 3 $1.43 -$32.56 $10.12 1.92 8.52 0.00 0.00 All Btype_Retro_DISP_LAMP_REPL_from Commercial Lighting INC_HAL to LED_PAR_MR 9 $9.28 -$77.90 -$35.22 3.49 37.61 0.00 0.01 All Btype_Retro_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LED_FIX_KIT 21 $36.92 -$3.98 $38.36 1.87 76.67 0.01 0.02 All Btype_Retro_HIGHBAY_FIX_REPL_from Commercial Lighting HID to LF2018 0 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 All Btype_Retro_HIGHBAY_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 20 $90.27 $39.65 $81.33 1.00 85.95 0.01 0.02 All Btype_Retro_LF_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT 16 $716.19 $130.30 $173.27 0.54 396.93 0.03 0.09 All Btype_Retro_LF_FIX_REPL_from Commercial Lighting LF2018 to LED_FIX_KIT_RDX 16 $302.24 $64.35 $107.33 0.80 264.87 0.02 0.06

Clark Public Utilities—Conservation Potential Assessment 98

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) All Btype_Retro_LF_FIX_REPL_from Commercial Lighting LF2018 to LF_FIX_KIT_RDX 20 $64.96 $34.40 $77.37 1.05 58.57 0.00 0.01 All Btype_Retro_LF_LAMP_REPL_from Commercial Lighting LF2018 to TLED_PIN 0 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 All Btype_Retro_LF_LAMP_REPL_from Commercial Lighting LF2018 to TLED_PIN_RDX 14 $398.68 $18.29 $61.26 1.23 560.12 0.05 0.12 All Btype_Retro_OTHER_LAMP_REPL_from Commercial Lighting CFL to LED_OMNI 8 $38.07 -$43.06 $0.37 1.78 70.59 0.01 0.02 All Btype_Retro_OTHER_LAMP_REPL_from Commercial Lighting HID to LED_OMNI 0 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 All Btype_Retro_OTHER_LAMP_REPL_from Commercial Lighting INC_HAL to CFL_OMNI 3 $1.23 -$117.28 -$74.45 6.45 24.79 0.00 0.01 All Btype_Retro_OTHER_LAMP_REPL_from Commercial Lighting INC_HAL to LED_OMNI 8 $6.31 -$131.95 -$89.12 11.73 111.37 0.01 0.02 Commercial Motors MotorsRewind-New-Anchor 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-New-Assembly 10 $2.14 -$4.49 $40.21 2.06 8.07 0.00 0.00 Commercial Motors MotorsRewind-New-Big Box 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-New-High End 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-New-Hospital 10 $0.86 -$31.19 $13.51 6.12 9.70 0.00 0.00 Commercial Motors MotorsRewind-New-K-12 10 $1.12 -$2.82 $41.88 1.97 4.04 0.00 0.00 Commercial Motors MotorsRewind-New-Large Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-New-Lodging 10 $0.72 -$32.73 $11.97 6.91 9.08 0.00 0.00 Commercial Motors MotorsRewind-New-Medium Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-New-MIniMart 10 $4.00 -$27.95 $16.75 4.93 36.14 0.00 0.00 Commercial Motors MotorsRewind-New-Other 10 $1.81 -$11.19 $33.50 2.47 8.18 0.00 0.00 Commercial Motors MotorsRewind-New-OtherHealth 10 $0.77 -$32.73 $11.97 6.91 9.70 0.00 0.00 Commercial Motors MotorsRewind-New-Restaurant 10 $4.82 -$19.57 $25.13 3.29 29.06 0.00 0.00 Commercial Motors MotorsRewind-New-Small Box 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-New-Small Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-New-Supermarket 10 $4.00 -$27.95 $16.75 4.93 36.14 0.00 0.00

Clark Public Utilities—Conservation Potential Assessment 99

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Motors MotorsRewind-New-University 10 $1.12 -$2.82 $41.88 1.97 4.04 0.00 0.00 Commercial Motors MotorsRewind-New-Warehouse 10 $1.06 -$2.82 $41.88 1.97 3.84 0.00 0.00 Commercial Motors MotorsRewind-NR-Anchor 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-NR-Assembly 10 $2.14 -$4.49 $40.21 2.06 8.07 0.00 0.00 Commercial Motors MotorsRewind-NR-Big Box 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-NR-High End 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-NR-Hospital 10 $0.86 -$31.19 $13.51 6.12 9.70 0.00 0.00 Commercial Motors MotorsRewind-NR-K-12 10 $1.12 -$2.82 $41.88 1.97 4.04 0.00 0.00 Commercial Motors MotorsRewind-NR-Large Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-NR-Lodging 10 $0.72 -$32.73 $11.97 6.91 9.08 0.00 0.00 Commercial Motors MotorsRewind-NR-Medium Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-NR-MIniMart 10 $4.00 -$27.95 $16.75 4.93 36.14 0.00 0.00 Commercial Motors MotorsRewind-NR-Other 10 $1.81 -$11.19 $33.50 2.47 8.18 0.00 0.00 Commercial Motors MotorsRewind-NR-OtherHealth 10 $0.77 -$32.73 $11.97 6.91 9.70 0.00 0.00 Commercial Motors MotorsRewind-NR-Restaurant 10 $4.82 -$19.57 $25.13 3.29 29.06 0.00 0.00 Commercial Motors MotorsRewind-NR-Small Box 10 $1.50 -$16.78 $27.92 2.96 8.13 0.00 0.00 Commercial Motors MotorsRewind-NR-Small Off 10 $2.81 -$2.82 $41.88 1.97 10.16 0.00 0.00 Commercial Motors MotorsRewind-NR-Supermarket 10 $4.00 -$27.95 $16.75 4.93 36.14 0.00 0.00 Commercial Motors MotorsRewind-NR-University 10 $1.12 -$2.82 $41.88 1.97 4.04 0.00 0.00 Commercial Motors MotorsRewind-NR-Warehouse 10 $1.06 -$2.82 $41.88 1.97 3.84 0.00 0.00 Networked Computer Control K-12 Commercial PC Network/Supply School-Wt HVAC 5 $11.94 -$3.81 $30.67 2.28 105.16 0.01 0.02 Commercial PC Network/Supply Smart Plug Power Strips-Retro 4 $36.62 $45.60 $94.73 0.88 127.35 0.00 0.09 Commercial Refrigeration Anti Sweat Heater Controls 8 $42.38 -$6.63 $23.39 2.48 327.96 0.02 0.07 ECM Controllers on Walk-In Evaporator Commercial Refrigeration Motors 16 $145.30 $12.82 $49.63 1.51 315.37 0.02 0.07 Commercial Refrigeration Floating Head Pressure Control 15 $295.40 $5.51 $42.32 1.77 785.41 0.04 0.18 Commercial Refrigeration Grocery Retrocommissioning 15 $0.26 -$9.80 $27.01 2.77 1.07 0.00 0.00 Commercial Refrigeration LED Case Lighting 6 $41.82 $71.17 $99.20 0.75 76.10 0.01 0.01

Clark Public Utilities—Conservation Potential Assessment 100

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Refrigeration LED Motion Sensors on Display Case 8 $3.27 $8.59 $43.45 1.69 13.63 0.00 0.00 Replace Shaded Pole with ECM in Walk- Commercial Refrigeration in Cooler 15 $6,353.96 -$7.87 $28.94 2.58 24,703.85 1.22 5.53 Strip Curtains: Walk-In Coolers/ Commercial Refrigeration Freezers 2 $9.15 -$0.51 $36.30 2.06 158.17 0.01 0.04 Commercial Refrigeration Market Average to ES 2.0 Upgrade 6 $31.61 $23.48 $65.58 1.26 111.05 0.01 0.04 Commercial Refrigeration Timer on ES 2.0 Cold Only Water Cooler 6 $22.89 $104.52 $140.14 0.53 37.63 0.00 0.01 Timer on ES 2.0 Hot & Cold Water Commercial Refrigeration Cooler 6 $22.89 -$16.30 $25.79 3.21 204.46 0.02 0.07 Commercial Rooftop Units Economizer-Retro-Anchor 18 $134.43 $10.28 $51.07 1.56 736.46 0.00 0.21 Commercial Rooftop Units Economizer-Retro-Assembly 18 $185.66 $62.51 $121.90 0.80 350.46 0.00 0.10 Commercial Rooftop Units Economizer-Retro-Big Box 18 $259.52 $69.53 $116.70 0.74 429.20 0.00 0.12 Commercial Rooftop Units Economizer-Retro-High End 18 $164.18 $15.78 $58.15 1.39 697.87 0.00 0.20 Commercial Rooftop Units Economizer-Retro-Hospital 18 $261.12 $94.09 $160.11 0.65 313.83 0.00 0.09 Commercial Rooftop Units Economizer-Retro-K-12 18 $176.65 $66.28 $129.65 0.79 322.58 0.00 0.09 Commercial Rooftop Units Economizer-Retro-Large Off 18 $143.51 $39.53 $89.49 0.99 430.40 0.00 0.12 Commercial Rooftop Units Economizer-Retro-Lodging 18 $113.06 $21.73 $63.80 1.27 556.09 0.00 0.16 Commercial Rooftop Units Economizer-Retro-Medium Off 18 $165.57 $43.55 $92.69 0.95 439.31 0.00 0.13 Commercial Rooftop Units Economizer-Retro-MIniMart 18 $230.32 $134.25 $187.19 0.49 252.02 0.00 0.07 Commercial Rooftop Units Economizer-Retro-Other 18 $167.21 $51.66 $108.10 0.88 378.17 0.00 0.11 Commercial Rooftop Units Economizer-Retro-OtherHealth 18 $137.62 $31.10 $76.82 1.10 493.76 0.00 0.14 Commercial Rooftop Units Economizer-Retro-Restaurant 18 $224.18 $60.29 $106.01 0.80 439.25 0.00 0.13 Commercial Rooftop Units Economizer-Retro-Small Box 18 $281.80 $77.17 $125.31 0.69 417.43 0.00 0.12 Commercial Rooftop Units Economizer-Retro-Small Off 18 $119.04 $27.65 $71.70 1.15 503.14 0.00 0.14 Commercial Rooftop Units Economizer-Retro-Supermarket 18 $126.59 $146.14 $194.86 0.45 189.01 0.00 0.05 Commercial Rooftop Units Economizer-Retro-University 18 $184.45 $63.46 $123.88 0.80 343.88 0.00 0.10 Commercial Rooftop Units Economizer-Retro-Warehouse 18 $65.89 $38.37 $110.77 1.00 277.86 0.00 0.08 Street/Roadway Commercial Lighting Streetlight - HPS 100W - New 12 -$7.76 -$130.67 -$95.27 9,999.00 328.08 0.01 0.06 Street/Roadway Commercial Lighting Streetlight - HPS 100W - NR 12 $102.41 -$86.36 -$50.96 3.99 328.08 0.01 0.06 Commercial Street/Roadway Streetlight - HPS 250W - New 12 $1.82 -$77.55 -$42.14 343.16 716.23 0.03 0.13

Clark Public Utilities—Conservation Potential Assessment 101

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Lighting Street/Roadway Commercial Lighting Streetlight - HPS 250W - NR 12 $146.31 -$50.93 -$15.53 4.26 716.23 0.03 0.13 Street/Roadway Commercial Lighting Streetlight - MH 1000W - New 12 $480.49 -$25.09 $10.31 4.07 3,137.56 0.14 0.58 Street/Roadway Commercial Lighting Streetlight - MH 1000W - NR 12 $877.83 -$8.38 $27.02 2.23 3,137.56 0.14 0.58 Street/Roadway Commercial Lighting Streetlight - MH 200W - New 12 $1.82 -$106.41 -$71.00 255.27 425.12 0.02 0.08 Street/Roadway Commercial Lighting Streetlight - MH 200W - NR 12 $146.31 -$61.56 -$26.16 3.17 425.12 0.02 0.08 Street/Roadway Commercial Lighting Streetlight - MH 400W - New 12 $121.03 -$47.46 -$12.06 7.55 1,238.39 0.05 0.23 Street/Roadway Commercial Lighting Streetlight - MH 400W - NR 12 $292.61 -$29.18 $6.22 3.12 1,238.39 0.05 0.23 Demand Control Ventilation-Retro- Commercial Ventilation Anchor 15 $144.90 -$3.01 $43.22 1.99 377.25 0.03 0.19 Demand Control Ventilation-Retro- Commercial Ventilation Assembly 15 $197.55 $171.89 $213.83 0.37 103.96 0.00 0.04 Demand Control Ventilation-Retro-Big Commercial Ventilation Box 15 $478.78 $20.33 $70.80 1.30 760.99 0.06 0.48 Demand Control Ventilation-Retro-High Commercial Ventilation End 15 $244.42 $24.84 $73.02 1.22 376.67 0.03 0.21 Demand Control Ventilation-Retro- Commercial Ventilation Hospital 15 $102.92 $348.36 $389.11 0.21 29.76 0.00 0.01 Commercial Ventilation Demand Control Ventilation-Retro-K-12 15 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Demand Control Ventilation-Retro- Commercial Ventilation Large Off 15 $77.27 $17.16 $60.02 1.39 144.88 0.01 0.05 Demand Control Ventilation-Retro- Commercial Ventilation Lodging 15 $102.31 $18.96 $60.56 1.33 190.09 0.02 0.07 Demand Control Ventilation-Retro- Commercial Ventilation Medium Off 15 $105.80 $57.52 $102.15 0.84 116.56 0.01 0.05 Demand Control Ventilation-Retro- Commercial Ventilation MIniMart 15 $201.92 $69.37 $122.58 0.79 185.36 0.02 0.13 Demand Control Ventilation-Retro- Commercial Ventilation Other 15 $95.03 $118.55 $159.49 0.50 67.05 0.00 0.02 Demand Control Ventilation-Retro- Commercial Ventilation OtherHealth 15 $91.25 $35.42 $77.37 1.04 132.72 0.01 0.05 Demand Control Ventilation-Retro- Commercial Ventilation Restaurant 15 $269.99 $13.42 $62.75 1.46 484.18 0.05 0.28 Demand Control Ventilation-Retro- Commercial Ventilation Small Box 15 $333.16 $54.08 $107.15 0.90 349.89 0.03 0.24

Clark Public Utilities—Conservation Potential Assessment 102

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Demand Control Ventilation-Retro- Commercial Ventilation Small Off 15 $98.72 $29.68 $74.28 1.16 149.55 0.02 0.06 Demand Control Ventilation-Retro- Commercial Ventilation Supermarket 15 $255.52 $5.21 $56.17 1.66 511.92 0.05 0.33 Demand Control Ventilation-Retro- Commercial Ventilation University 15 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Demand Control Ventilation-Retro- Commercial Ventilation Warehouse 15 $19.68 $1,919.11 $1,998.11 0.06 1.11 0.00 0.00 Commercial Ventilation ECM-VAV-New-Anchor 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Assembly 18 $33.64 $46.43 $26.88 0.91 124.83 0.01 0.03 Commercial Ventilation ECM-VAV-New-Big Box 18 $5.88 $294.59 $25.38 0.23 23.12 0.00 0.00 Commercial Ventilation ECM-VAV-New-High End 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Hospital 18 $72.21 $13.52 $25.44 1.52 283.04 0.02 0.06 Commercial Ventilation ECM-VAV-New-K-12 18 $24.03 $65.93 $26.11 0.75 91.77 0.01 0.02 Commercial Ventilation ECM-VAV-New-Large Off 18 $112.17 $10.79 $29.94 1.62 373.67 0.03 0.08 Commercial Ventilation ECM-VAV-New-Lodging 18 $7.00 $353.44 $34.75 0.18 20.09 0.00 0.00 Commercial Ventilation ECM-VAV-New-Medium Off 18 $9.08 $229.92 $30.31 0.30 29.87 0.00 0.01 Commercial Ventilation ECM-VAV-New-MIniMart 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Other 18 $39.55 $39.67 $27.50 0.99 143.45 0.01 0.03 Commercial Ventilation ECM-VAV-New-OtherHealth 18 $5.51 $411.51 $31.99 0.15 17.19 0.00 0.00 Commercial Ventilation ECM-VAV-New-Restaurant 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Small Box 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Small Off 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-Supermarket 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-New-University 18 $72.21 $15.44 $26.64 1.47 270.29 0.02 0.06 Commercial Ventilation ECM-VAV-New-Warehouse 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Anchor 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Assembly 18 $33.64 $35.99 $24.41 1.04 137.43 0.01 0.03 Commercial Ventilation ECM-VAV-NR-Big Box 18 $5.88 $252.08 $23.23 0.27 25.26 0.00 0.01 Commercial Ventilation ECM-VAV-NR-High End 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Hospital 18 $72.21 $7.81 $23.28 1.71 309.34 0.02 0.07

Clark Public Utilities—Conservation Potential Assessment 103

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Ventilation ECM-VAV-NR-K-12 18 $24.03 $53.17 $23.81 0.85 100.65 0.01 0.02 Commercial Ventilation ECM-VAV-NR-Large Off 18 $112.17 $4.96 $26.76 1.81 417.98 0.04 0.09 Commercial Ventilation ECM-VAV-NR-Lodging 18 $7.00 $287.33 $30.34 0.23 23.01 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Medium Off 18 $9.08 $190.41 $27.05 0.34 33.48 0.00 0.01 Commercial Ventilation ECM-VAV-NR-MIniMart 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Other 18 $39.55 $29.97 $24.90 1.14 158.44 0.01 0.03 Commercial Ventilation ECM-VAV-NR-OtherHealth 18 $5.51 $340.21 $28.30 0.18 19.43 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Restaurant 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Small Box 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Small Off 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-Supermarket 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Ventilation ECM-VAV-NR-University 18 $72.21 $9.44 $24.23 1.63 297.25 0.03 0.06 Commercial Ventilation ECM-VAV-NR-Warehouse 18 $0.00 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-Anchor 50 $2,300.00 $60.27 $95.15 0.78 1,559.00 0.06 0.40 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-K-12 50 $2,099.79 $140.27 $169.42 0.44 799.35 0.07 0.17 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-Large Off 50 $2,300.23 $71.14 $107.67 0.71 1,377.94 0.05 0.34 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-Medium Off 50 $2,300.23 $71.14 $107.67 0.71 1,377.94 0.05 0.34 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-Other 50 $2,033.66 $71.87 $108.18 0.71 1,212.51 0.04 0.30 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-OtherHealth 50 $2,168.21 $75.52 $107.88 0.58 1,296.28 -0.10 0.31 Low Pressure Distribution Complex Commercial Ventilation HVAC-New-University 50 $2,001.00 $73.15 $108.27 0.67 1,191.99 0.01 0.28 Commercial Ventilation Premium Fume Hood-NR 18 $7,200.00 $7.22 $46.12 1.71 15,569.13 1.73 3.73 Commercial Ventilation VRF-New-Anchor 20 $1,677.80 $59.64 $97.35 0.80 1,609.71 0.17 0.33 Commercial Ventilation VRF-New-Assembly 20 $2,651.11 $21.81 $59.52 1.30 4,160.19 0.44 0.85 Commercial Ventilation VRF-New-Big Box 20 $2,067.47 $45.89 $83.60 0.93 2,309.82 0.25 0.47

Clark Public Utilities—Conservation Potential Assessment 104

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Ventilation VRF-New-High End 20 $2,487.52 $48.29 $86.00 0.90 2,701.57 0.29 0.55 Commercial Ventilation VRF-New-Hospital 20 $3,459.13 $49.71 $87.42 0.89 3,695.79 0.39 0.75 Commercial Ventilation VRF-New-K-12 20 $1,957.24 $60.25 $97.97 0.79 1,866.09 0.20 0.38 Commercial Ventilation VRF-New-Large Off 20 $3,297.91 $39.36 $77.08 1.01 3,996.35 0.42 0.82 Commercial Ventilation VRF-New-Lodging 20 $3,121.09 $31.37 $69.09 1.12 4,219.50 0.45 0.86 Commercial Ventilation VRF-New-Medium Off 20 $2,257.59 $38.34 $76.06 1.02 2,772.43 0.29 0.57 Commercial Ventilation VRF-New-MIniMart 20 $4,947.97 $35.44 $73.15 1.06 6,317.68 0.67 1.29 Commercial Ventilation VRF-New-Other 20 $2,393.81 $15.36 $53.07 1.46 4,212.93 0.45 0.86 Commercial Ventilation VRF-New-OtherHealth 20 $4,105.91 $54.47 $92.19 0.84 4,160.19 0.44 0.85 Commercial Ventilation VRF-New-Restaurant 20 $4,635.81 $33.99 $71.71 1.08 6,038.14 0.64 1.23 Commercial Ventilation VRF-New-Small Box 20 $2,104.86 $41.48 $79.20 0.98 2,482.41 0.26 0.51 Commercial Ventilation VRF-New-Small Off 20 $1,645.15 $10.55 $48.27 1.61 3,183.64 0.34 0.65 Commercial Ventilation VRF-New-Supermarket 20 $4,462.17 $35.01 $72.73 1.07 5,730.55 0.61 1.17 Commercial Ventilation VRF-New-University 20 $2,336.85 $66.18 $103.89 0.75 2,100.93 0.22 0.43 Commercial Ventilation VRF-New-Warehouse 20 $2,067.47 $45.89 $83.60 0.93 2,309.82 0.25 0.47 Commercial Ventilation VRF-Retro-Anchor 20 $2,512.97 $75.02 $112.74 0.69 2,082.03 0.22 0.43 Commercial Ventilation VRF-Retro-Assembly 20 $2,700.81 $41.06 $78.77 0.99 3,202.45 0.34 0.65 Commercial Ventilation VRF-Retro-Big Box 20 $2,978.49 $91.67 $129.39 0.60 2,150.08 0.23 0.44 Commercial Ventilation VRF-Retro-High End 20 $2,836.77 $86.72 $124.43 0.62 2,129.36 0.23 0.43 Commercial Ventilation VRF-Retro-Hospital 20 $4,700.22 $65.15 $102.87 0.75 4,267.68 0.45 0.87 Commercial Ventilation VRF-Retro-K-12 20 $2,782.39 $93.40 $131.12 0.59 1,982.06 0.21 0.40 Commercial Ventilation VRF-Retro-Large Off 20 $3,108.48 $35.21 $72.93 1.06 3,981.02 0.42 0.81 Commercial Ventilation VRF-Retro-Lodging 20 $2,778.68 $31.06 $68.77 1.13 3,773.88 0.40 0.77 Commercial Ventilation VRF-Retro-Medium Off 20 $1,893.54 $35.83 $73.55 1.06 2,404.75 0.26 0.49 Commercial Ventilation VRF-Retro-MIniMart 20 $5,019.41 $45.68 $83.40 0.93 5,621.79 0.60 1.15 Commercial Ventilation VRF-Retro-Other 20 $2,713.97 $21.15 $58.86 1.32 4,306.41 0.46 0.88 Commercial Ventilation VRF-Retro-OtherHealth 20 $3,405.20 $42.05 $79.77 0.97 3,987.31 0.42 0.81 Commercial Ventilation VRF-Retro-Restaurant 20 $4,708.09 $37.69 $75.40 1.03 5,832.05 0.62 1.19

Clark Public Utilities—Conservation Potential Assessment 105

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Ventilation VRF-Retro-Small Box 20 $3,068.09 $94.76 $132.48 0.59 2,163.18 0.23 0.44 Commercial Ventilation VRF-Retro-Small Off 20 $1,601.15 $4.34 $42.06 1.85 3,556.00 0.38 0.73 Commercial Ventilation VRF-Retro-Supermarket 20 $2,896.09 $43.85 $81.56 0.95 3,316.49 0.35 0.68 Commercial Ventilation VRF-Retro-University 20 $2,750.52 $86.54 $124.25 0.62 2,067.62 0.22 0.42 Commercial Ventilation VRF-Retro-Warehouse 20 $3,068.09 $58.47 $96.19 0.81 2,979.37 0.32 0.61 Commercial Ventilation WEPT-Retro-Anchor 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Assembly 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Big Box 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-High End 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Hospital 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-K-12 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Large Off 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Lodging 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Medium Off 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-MIniMart 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Other 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-OtherHealth 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Restaurant 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Small Box 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Small Off 5 $577.96 $41.75 $79.47 0.98 1,825.01 0.19 0.37 Commercial Ventilation WEPT-Retro-Supermarket 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-University 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Ventilation WEPT-Retro-Warehouse 5 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Anchor 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Assembly 10 $10.24 -$667.69 $29.17 25.19 53.17 0.00 0.01 Commercial Water Heat Showerheads-Retro-Big Box 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-High End 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Hospital 10 $10.24 -$355.92 $20.95 19.81 74.06 0.01 0.01

Clark Public Utilities—Conservation Potential Assessment 106

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Water Heat Showerheads-Retro-K-12 10 $10.24 -$647.10 $49.76 14.77 31.17 0.00 0.00 Commercial Water Heat Showerheads-Retro-Large Off 10 $10.24 -$234.10 $17.77 16.31 87.31 0.01 0.01 Commercial Water Heat Showerheads-Retro-Lodging 10 $10.24 -$667.69 $29.17 25.19 53.17 0.00 0.01 Commercial Water Heat Showerheads-Retro-Medium Off 10 $10.24 -$234.10 $17.77 16.31 87.31 0.01 0.01 Commercial Water Heat Showerheads-Retro-MIniMart 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Other 10 $10.24 -$375.94 $0.93 445.70 1,666.56 0.12 0.19 Commercial Water Heat Showerheads-Retro-OtherHealth 10 $10.24 -$667.69 $29.17 25.19 53.17 0.00 0.01 Commercial Water Heat Showerheads-Retro-Restaurant 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Small Box 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-Small Off 10 $10.24 -$234.10 $17.77 16.31 87.31 0.01 0.01 Commercial Water Heat Showerheads-Retro-Supermarket 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat Showerheads-Retro-University 10 $10.24 -$667.69 $29.17 25.19 53.17 0.00 0.01 Commercial Water Heat Showerheads-Retro-Warehouse 10 $10.24 $9,999.00 $9,999.00 0.00 0.00 0.00 0.00 Commercial Water Heat WHTanks-New-Anchor 41 $0.00 -$33.87 $0.00 9,999.00 8.59 0.00 0.00 Commercial Water Heat WHTanks-New-Assembly 79 $0.00 -$33.87 $0.00 9,999.00 19.33 0.00 0.00 Commercial Water Heat WHTanks-New-Big Box 41 $0.00 -$33.87 $0.00 9,999.00 5.37 0.00 0.00 Commercial Water Heat WHTanks-New-High End 41 $0.00 -$33.87 $0.00 9,999.00 7.52 0.00 0.00 Commercial Water Heat WHTanks-New-Hospital 49 $0.00 -$33.87 $0.00 9,999.00 17.19 0.00 0.00 Commercial Water Heat WHTanks-New-K-12 94 $0.00 -$33.87 $0.00 9,999.00 9.67 0.00 0.00 Commercial Water Heat WHTanks-New-Large Off 49 $0.00 -$33.87 $0.00 9,999.00 2.15 0.00 0.00 Commercial Water Heat WHTanks-New-Lodging 60 $0.00 -$33.87 $0.00 9,999.00 16.11 0.00 0.00 Commercial Water Heat WHTanks-New-Medium Off 49 $0.00 -$33.87 $0.00 9,999.00 3.22 0.00 0.00 Commercial Water Heat WHTanks-New-MIniMart 57 $0.00 -$33.87 $0.00 9,999.00 13.96 0.00 0.00 Commercial Water Heat WHTanks-New-Other 59 $0.00 -$33.87 $0.00 9,999.00 20.41 0.00 0.00 Commercial Water Heat WHTanks-New-OtherHealth 49 $0.00 -$33.87 $0.00 9,999.00 18.26 0.00 0.00 Commercial Water Heat WHTanks-New-Restaurant 84 $0.00 -$33.87 $0.00 9,999.00 15.04 0.00 0.00 Commercial Water Heat WHTanks-New-Small Box 41 $0.00 -$33.87 $0.00 9,999.00 6.44 0.00 0.00 Commercial Water Heat WHTanks-New-Small Off 49 $0.00 -$33.87 $0.00 9,999.00 4.30 0.00 0.00

Clark Public Utilities—Conservation Potential Assessment 107

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Commercial Water Heat WHTanks-New-Supermarket 57 $0.00 -$33.87 $0.00 9,999.00 12.89 0.00 0.00 Commercial Water Heat WHTanks-New-University 49 $0.00 -$33.87 $0.00 9,999.00 10.74 0.00 0.00 Commercial Water Heat WHTanks-New-Warehouse 54 $0.00 -$33.87 $0.00 9,999.00 11.82 0.00 0.00 Commercial Water Heat WHTanks-NR-Anchor 41 $0.00 -$33.87 $0.00 9,999.00 8.59 0.00 0.00 Commercial Water Heat WHTanks-NR-Assembly 79 $0.00 -$33.87 $0.00 9,999.00 19.33 0.00 0.00 Commercial Water Heat WHTanks-NR-Big Box 41 $0.00 -$33.87 $0.00 9,999.00 5.37 0.00 0.00 Commercial Water Heat WHTanks-NR-High End 41 $0.00 -$33.87 $0.00 9,999.00 7.52 0.00 0.00 Commercial Water Heat WHTanks-NR-Hospital 49 $0.00 -$33.87 $0.00 9,999.00 17.19 0.00 0.00 Commercial Water Heat WHTanks-NR-K-12 94 $0.00 -$33.87 $0.00 9,999.00 9.67 0.00 0.00 Commercial Water Heat WHTanks-NR-Large Off 49 $0.00 -$33.87 $0.00 9,999.00 2.15 0.00 0.00 Commercial Water Heat WHTanks-NR-Lodging 60 $0.00 -$33.87 $0.00 9,999.00 16.11 0.00 0.00 Commercial Water Heat WHTanks-NR-Medium Off 49 $0.00 -$33.87 $0.00 9,999.00 3.22 0.00 0.00 Commercial Water Heat WHTanks-NR-MIniMart 57 $0.00 -$33.87 $0.00 9,999.00 13.96 0.00 0.00 Commercial Water Heat WHTanks-NR-Other 59 $0.00 -$33.87 $0.00 9,999.00 20.41 0.00 0.00 Commercial Water Heat WHTanks-NR-OtherHealth 49 $0.00 -$33.87 $0.00 9,999.00 18.26 0.00 0.00 Commercial Water Heat WHTanks-NR-Restaurant 84 $0.00 -$33.87 $0.00 9,999.00 15.04 0.00 0.00 Commercial Water Heat WHTanks-NR-Small Box 41 $0.00 -$33.87 $0.00 9,999.00 6.44 0.00 0.00 Commercial Water Heat WHTanks-NR-Small Off 49 $0.00 -$33.87 $0.00 9,999.00 4.30 0.00 0.00 Commercial Water Heat WHTanks-NR-Supermarket 57 $0.00 -$33.87 $0.00 9,999.00 12.89 0.00 0.00 Commercial Water Heat WHTanks-NR-University 49 $0.00 -$33.87 $0.00 9,999.00 10.74 0.00 0.00 Commercial Water Heat WHTanks-NR-Warehouse 54 $0.00 -$33.87 $0.00 9,999.00 11.82 0.00 0.00 Optimize Municipal Sewage ; <1 MGD Commercial Water_Wastewater Design Capacity 12 $45,959.30 $0.81 $34.79 1.61 100,072.81 7.31 11.42 Optimize Municipal Sewage ; >10 MGD Commercial Water_Wastewater Design Capacity 12 $8,085.64 -$34.73 -$0.74 3.90 42,569.98 3.11 4.86 Optimize Municipal Sewage ; 1 to 10 Commercial Water_Wastewater MGD Design Capacity 12 $42,736.43 $9.98 $43.97 1.40 80,819.71 5.90 9.23 Commercial Water_Wastewater Municipal Water Supply-Retro 12 $12,879.84 -$4.02 $29.96 2.40 56,720.80 4.14 6.47 38,015,476. Industrial Compressed Air Air Compressor Demand Reduction 10 $30,805.12 -$11.29 $34.14 2.42 00 3,944.11 5,636.01

Clark Public Utilities—Conservation Potential Assessment 108

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Industrial Compressed Air Air Compressor Equipment1 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 20,428,250. Industrial Compressed Air Air Compressor Equipment2 10 $1,438.21 -$13.63 $32.01 2.59 00 2,119.43 3,028.61 59,924,220. Industrial Compressed Air Air Compressor Optimization 10 $13,375.35 -$37.28 $50.97 2.41 00 6,217.15 8,884.11 22,294,024. Industrial Fans Efficient Centrifugal Fan 10 $5,355.24 -$16.82 $25.42 2.95 00 1,624.18 2,659.91 83,470,544. Industrial Fans Fan Energy Management 10 $0.00 -$17.17 $27.94 2.98 00 5,886.79 10,789.35 233,949,64 Industrial Fans Fan Equipment Upgrade 10 $123,893.01 -$5.44 $39.88 2.07 8.00 24,272.31 34,684.39 247,291,37 Industrial Fans Fan System Optimization 10 $94,317.32 -$28.50 $51.42 2.27 6.00 27,116.84 40,197.71 37,799,792. Industrial Fans Paper: Premium Fan 10 $7,644.26 -$19.51 $24.53 3.16 00 3,921.73 5,604.04 16,511,011. Industrial Lighting Efficient Lighting 1 Shift 10 $11,944.13 -$38.08 $10.80 7.63 00 1,802.87 4,120.34 15,658,791. Industrial Lighting Efficient Lighting 2 Shift 10 $6,582.66 -$42.29 $6.28 12.97 00 1,709.81 3,529.93 142,430,16 Industrial Lighting Efficient Lighting 3 Shift 10 $34,174.45 -$42.78 $3.41 22.72 0.00 14,777.15 21,116.09 17,276,740. Industrial Lighting HighBay Lighting 1 Shift 10 $40,846.56 -$11.09 $35.31 2.33 00 1,886.48 4,311.42 16,391,891. Industrial Lighting HighBay Lighting 2 Shift 10 $22,511.41 -$26.61 $20.51 3.97 00 1,789.86 3,695.20 149,640,76 Industrial Lighting HighBay Lighting 3 Shift 10 $116,242.68 -$34.31 $11.09 6.98 8.00 15,525.25 22,185.11 40,546,528. Industrial Lighting Lighting Controls 10 $89,556.64 -$11.42 $31.87 2.43 00 4,206.71 6,011.26 17,070,028. Industrial Motors Motors: Rewind 101-200 HP 10 $24,947.66 -$11.46 $31.83 2.43 00 1,771.02 2,530.73 14,369,851. Industrial Motors Motors: Rewind 201-500 HP 10 $7,615.57 -$24.22 $20.25 3.82 00 1,490.87 2,130.41 21,860,736. Industrial Motors Motors: Rewind 20-50 HP 10 $53,860.93 $7.42 $48.97 1.58 00 2,268.05 3,240.98 18,856,572. Industrial Motors Motors: Rewind 501-5000 HP 10 $4,678.21 -$30.18 $14.84 5.22 00 1,956.37 2,795.60 11,417,371. Industrial Motors Motors: Rewind 51-100 HP 10 $14,262.91 $1.83 $43.90 1.76 00 1,184.55 1,692.69 Process: Electronic 27,928,274. Industrial Mfg Clean Room: Change Filter Strategy 1 $12,286.43 -$37.72 $8.71 9.68 00 2,897.56 4,140.53 Process: Electronic 11,890,339. Industrial Mfg Clean Room: Chiller Optimize 10 $67,499.69 -$32.88 $12.39 6.25 00 1,233.62 1,762.81

Clark Public Utilities—Conservation Potential Assessment 109

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) Process: Electronic 7,550,614.5 Industrial Mfg Clean Room: Clean Room HVAC 20 $88,718.99 -$29.98 $14.02 5.15 0 783.38 1,119.42 Process: Electronic 1,320,015.0 Industrial Mfg Elec Chip Fab: Eliminate Exhaust 10 $87,593.86 -$0.55 $41.74 1.85 0 136.95 195.70 Process: Electronic $4,062,932.8 42,070,120. Industrial Mfg Elec Chip Fab: Exhaust Injector 10 7 -$108.98 $60.74 3.21 00 4,364.78 6,237.14 Process: Electronic 10,835,147. Industrial Mfg Elec Chip Fab: Reduce Gas Pressure 10 $0.00 -$60.08 $0.00 9,999.00 00 1,124.15 1,606.37 Process: Electronic $5,143,210.9 47,160,288. Industrial Mfg Elec Chip Fab: Solidstate Chiller 10 3 -$89.35 $68.60 2.69 00 4,892.89 6,991.78 885,566,78 131,290.3 Industrial Process: General Energy Project Management 11 $266,554.98 -$1.16 $43.54 1.88 4.00 91,877.67 9 797,526,72 118,237.9 Industrial Process: General Integrated Plant Energy Management 11 $399,821.24 -$43.08 $61.07 2.28 0.00 82,743.50 4 Industrial Process: General Material Handling VFD1 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 242,173,64 Industrial Process: General Material Handling VFD2 10 $199,624.55 -$1.37 $41.54 1.88 8.00 26,555.65 39,365.81 Industrial Process: General Material Handling1 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 60,991,764. Industrial Process: General Material Handling2 10 $83,176.90 $28.58 $68.72 1.14 00 6,688.08 9,914.33 7,570,533.0 Industrial Process: General Panel: Hydraulic Press 10 $1,432.16 -$17.32 $27.05 2.89 0 830.15 1,230.61 415,157,02 Industrial Process: General Plant Energy Management 10 $71,470.68 -$16.50 $29.72 2.84 4.00 43,072.59 61,549.42 Industrial Process: General Synchronous Belts 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 58,027,784. Industrial Process: Kraft Mfg Kraft: Efficient Agitator 10 $0.00 -$33.90 $11.47 6.75 00 6,020.39 8,602.95 Industrial Process: Mech Mfg Mech Pulp: Premium Process 5 $0.00 -$15.60 $29.35 2.76 307,407.56 31.89 45.57 1,290,195.0 Industrial Process: Mech Mfg Mech Pulp: Refiner Plate Improvement 1 $0.00 -$1.58 $44.45 1.90 0 133.86 191.28 19,542,646. Industrial Process: Mech Mfg Mech Pulp: Refiner Replacement 12 $0.00 -$8.73 $29.71 1.63 00 2,027.55 2,897.31 2,368,379.2 Industrial Process: Metal Mfg Metal: New Arc Furnace 10 $1,043.86 -$1,895.15 $12.49 141.50 5 245.72 351.13 31,216,900. Industrial Process: Paper Mfg Paper: Efficient Pulp Screen 10 $6,282.93 -$19.64 $24.41 3.17 00 3,238.76 4,628.09 11,769,520. Industrial Process: Paper Mfg Paper: Large Material Handling 10 $7,446.28 $124.51 $155.27 0.50 00 1,221.09 1,744.90 7,703,869.0 Industrial Process: Paper Mfg Paper: Material Handling 10 $8,377.07 $98.74 $131.87 0.59 0 799.28 1,142.14 Industrial Process: Paper Mfg Paper: Premium Control Large Material 10 $8,190.91 $26.51 $66.30 1.17 30,317,342. 3,145.43 4,494.72

Clark Public Utilities—Conservation Potential Assessment 110

TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) 00 181,606,08 Industrial Process: Wood Mfg Wood: Replace Pneumatic Conveyor 10 $12,549.82 -$101.34 $1.96 66.08 0.00 19,914.09 29,520.43 7,069,498.5 Industrial Pumps Kraft: Effluent Treatment System 10 $0.00 -$35.51 $10.01 7.73 0 733.46 1,048.09 127,477,09 Industrial Pumps Pump Energy Management 10 $0.00 -$16.90 $27.93 2.96 6.00 9,287.06 15,209.36 344,630,24 Industrial Pumps Pump Equipment Upgrade 10 $159,335.97 $2.50 $45.54 1.75 0.00 25,107.27 41,118.01 353,053,53 Industrial Pumps Pump System Optimization 12 $339,649.44 -$53.15 $71.75 2.21 6.00 24,899.23 45,635.46 Refrigerated Industrial Storage CA Retrofit -- CO2 Scrub 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Refrigerated Industrial Storage CA Retrofit -- Membrane 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Refrigerated 38,675,904. Industrial Storage Cold Storage Retrofit 10 $0.00 -$1.08 $38.79 1.91 00 686.79 4,905.62 Refrigerated 25,670,564. Industrial Storage Cold Storage Tuneup 3 $0.00 -$13.69 $29.15 2.71 00 455.84 3,256.03 Refrigerated 141,455,37 Industrial Storage Food: Cooling and Storage 10 $258,506.30 $4.25 $43.62 1.70 6.00 2,511.89 17,942.08 Refrigerated 76,251,584. Industrial Storage Food: Refrig Storage Tuneup 3 $30,159.07 -$13.69 $29.15 2.71 00 1,354.04 9,671.69 Refrigerated 357,251,23 Industrial Storage Fruit Storage Refer Retrofit 10 $0.00 -$11.99 $33.05 2.37 2.00 16,886.99 90,482.12 Refrigerated 115,813,59 Industrial Storage Fruit Storage Tuneup 3 $0.00 -$18.27 $29.17 2.87 2.00 5,474.42 29,332.47 Refrigerated 10,572,361. Industrial Storage Groc Dist Retrofit 10 $0.00 $0.77 $40.46 1.83 00 187.74 1,340.99 Refrigerated 13,039,245. Industrial Storage Groc Dist Tuneup 3 $0.00 -$13.69 $29.15 2.71 00 231.54 1,653.89 Industrial Transformers Transformers-New 32 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 Industrial Transformers Transformers-Retrofit 10 $0.00 $9,999.00 $9,999.00 9,999.00 0.00 0.00 0.00 1 - Reduce system voltage w/ LDC voltage control 1 - Reduce system voltage w/ LDC DEI method voltage control method 15 $0.15 -$31.27 $5.09 14.83 4.13 0.00 0.00 2 - Light system improvements (var mgmt, phase load 2 - Light system improvements (var balancing, and mgmt, phase load balancing, and DEI feeder load feeder load balancing) 15 $0.23 -$25.98 $10.38 7.27 2.47 0.00 0.00

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TRC Measure Total Sponsor Wholesale Retail Initial Levelized TRC B/C Bulk Energy Sector End Use Measure Name Life Levelized Cost Demand Demand Capital Cost Cost Ratio (kWh/unit) (Years) ($/MWh) (kW) (kW) ($/MWh) balancing)

3 - Major system improvements (voltage regulators on 1 of 4 substations, and select 3 - Major system improvements reconductoring on (voltage regulators on 1 of 4 1 of every 2 substations, and select reconductoring DEI substations) on 1 of every 2 substations) 15 $1.63 $25.02 $61.38 1.23 2.72 0.00 0.00 4 - EOL voltage DEI control method 4 - EOL voltage control method 15 $1.26 $58.27 $94.63 0.80 1.39 0.00 0.00 A - SCL implement EOL w/ major system A - SCL implement EOL w/ major DEI improvements system improvements 15 $0.32 $261.42 $297.78 0.25 0.11 0.00 0.00

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