TECHNICAL USER GUIDE MANUAL
for the RETROFIT Engineered Worksheets
January 2015
Independent Electricity System Operator
120 Adelaide St. West
Suite 1600
Toronto, Ontario
M5H 1T1
For inquiries, please send them to
Technicalservices.conservation@ieso.ca
Table of Contents
1)
INTRODUCTION ............................................................................................................................................. 4
1.1
1.2
1.3
1.4
2)
DOCUMENT PURPOSE ........................................................................................................................................4
DISCLAIMER .....................................................................................................................................................4
DOCUMENT LAYOUT ..........................................................................................................................................4
DEFINITIONS ....................................................................................................................................................5
OVERVIEW .................................................................................................................................................... 6
2.1
THE RETROFIT ENGINEERED WORKSHEETS...........................................................................................................7
2.2
ENGINEERED WORKSHEET LAYOUT .......................................................................................................................7
2.2.1 Types of Cells............................................................................................................................................8
3)
THE APPLICANT AND FACILITY INFORMATION TAB ....................................................................................... 9
3.1
3.2
3.3
3.4
APPLICANT AND PROJECT CONTACT INFORMATION ..................................................................................................9
FACILITY INFORMATION ......................................................................................................................................9
FACILITY SCHEDULE .........................................................................................................................................10
BILLING DATA.................................................................................................................................................11
4)
THE SYSTEM SCHEDULE TAB ........................................................................................................................ 12
5)
THE SYSTEM DESIGN ASSUMPTIONS TAB .................................................................................................... 14
5.1
COMBINED COMMERCIAL LIGHTING ENGINEERED WORKSHEETS ..............................................................................14
5.1.1 Base Case and Retrofit Lighting System .................................................................................................15
5.1.2
Base Case and Retrofit Power Input.......................................................................................................17
5.2
LIGHTING CONTROLS ENGINEERED WORKSHEET ....................................................................................................18
5.2.1 Lighting Controls Overview ....................................................................................................................18
5.2.2
Lighting System Operating Schedule .....................................................................................................18
5.2.3
Space Information ..................................................................................................................................19
5.2.4
Lighting Information ..............................................................................................................................19
5.2.5
Daylighting Information .........................................................................................................................19
5.3
COMPRESSED AIR ENGINEERED WORKSHEET ........................................................................................................20
5.3.1 Compressed Air Systems Overview ........................................................................................................21
5.3.2
Start Here Tab ........................................................................................................................................22
Compressor Inventory .........................................................................................................................................24
Pipe Pressure and Volume Tests .........................................................................................................................26
5.3.3
Measure 1 – Reduce Air Leakage ...........................................................................................................28
5.3.4
Measure 2 – Reduce Discharge Pressure ...............................................................................................30
5.3.5
Measure 3 – Energy Efficient Dryer........................................................................................................31
5.3.6
Measure 4 – Zero Loss Drains Tab .........................................................................................................33
5.3.7
Summary of Measures, Energy Impact, Project Economics & Incentives...............................................33
5.3.8
Summary of Underlying Calculation and Assumptions ..........................................................................34
5.4
VARIABLE SPEED DRIVE (VSD) COMPRESSED AIR ENGINEERED WORKSHEET ..............................................................36
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5.4.1
Backgrounder - VSD and Fixed Speed Air Compressors .........................................................................36
5.4.2
Suitability of Use and Limitations ..........................................................................................................38
5.4.3
Typical Operating Pressure ....................................................................................................................39
5.4.4
Fixed Speed Compressor (CAGI Data Sheet Inputs) ................................................................................40
5.4.5
VSD Compressor (CAGI Data Sheet Inputs) ............................................................................................41
5.4.6
Typical Operating Profile .......................................................................................................................42
5.4.7
Short Explanation...................................................................................................................................43
5.4.8
Comments & Notes for Technical Reviewer to be Aware of ..................................................................43
5.5
VARIABLE SPEED DRIVE (VSD) ON FANS ENGINEERED WORKSHEET ..........................................................................43
5.5.1 Fan Overview .........................................................................................................................................43
5.5.2
Fan Curve and Operating Profile ............................................................................................................44
5.5.3
Fan and Motor Information ...................................................................................................................47
5.5.4
Fan and Motor Efficiency .......................................................................................................................48
5.6
VARIABLE SPEED DRIVE (VSD) ON PUMPS ENGINEERED WORKSHEET .......................................................................50
5.6.1 Pump Overview ......................................................................................................................................50
5.6.2
Pump Curve and Operating Profile ........................................................................................................50
5.6.3
Pump and Motor Information ................................................................................................................52
5.6.4
Pump and Motor Efficiency ....................................................................................................................53
5.7
UNITARY AIR CONDITIONING (A/C) ENGINEERED WORKSHEET ................................................................................54
5.7.1 Applicant and Space Information ..........................................................................................................55
5.7.2
Load Duration Curve ..............................................................................................................................56
5.7.3
System Operating Schedule – Cooling Season Only ...............................................................................57
5.7.4
Floor Area and Climate ..........................................................................................................................57
5.7.5
Existing AC Unit and Replacement Unit Cost .........................................................................................58
5.8
PROJECT COST BREAKDOWN INFORMATION .........................................................................................................58
5.8.1 Economic Values ....................................................................................................................................58
5.8.2
6)
Project Cost Breakdown .........................................................................................................................60
OUTPUTS TAB .............................................................................................................................................. 61
6.1
PROJECT ENGINEERING ESTIMATES .....................................................................................................................61
6.1.1 Combined Commercial Lighting .............................................................................................................62
6.1.2
Lighting Controls ....................................................................................................................................62
6.1.3
Compressed Air ......................................................................................................................................69
6.1.4
Variable Speed Drive Compressed Air ....................................................................................................69
6.1.5
Variable Speed Drive on Fans.................................................................................................................70
6.1.6
Variable Speed Drive on Pumps .............................................................................................................72
6.1.7
Unitary A/C ............................................................................................................................................74
6.2
PROJECT ECONOMICS.......................................................................................................................................74
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6.3
QUALITY CONTROL (QC) AND DIAGNOSTICS FOR LDCS ..........................................................................................75
APPENDIX A –Examples of Completed Engineered Worksheets
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1)
INTRODUCTION
1.1
DOCUMENT PURPOSE
This Technical User Guide Manual (the “Guide”) is has been developed to help Local Distribution
Companies (LDCs), Applicants and their respective Representatives, Project Consultants and Project
Evaluators complete the Engineered Worksheets (Microsoft Excel spreadsheets) that are part of the
RETROFIT PROGRAM. The Guide describes how the Engineered Worksheets calculate the Participant
Incentives. It is not related to any specific version of the Engineered Worksheets.
1.2
DISCLAIMER
This Guide and its appendices are provided solely for informational purposes and based on information
currently available to the Independent Electricity System Operator (“IESO”). The IESO expressly
disclaims any responsibility or liability for any other use of the information in the Guide or any methods
or equipment described. In particular, the information in the Guide is not meant to be relied on to
determine or project actual electricity or cost savings, or to calculate progress towards conservation and
demand management targets set by the Ontario Energy Board. The IESO does not warrant the accuracy,
reliability, completeness or timeliness of any of the information contained in the Guide, including any
third party information and information of the Department of Natural Resources Canada (“NRCan”), and
undertakes no obligation to revise or update the Guide. Users of this Guide rely on the information
contained therein at their own risk and remain responsible for seeking appropriate legal, technical or
other professional advice with regard to their particular circumstances. The IESO and its respective
officers, directors, employees, consultants, agents and subcontractors assume no liability or
responsibility whatsoever to any person for damages of whatever kind and nature, which may occur or
be suffered as a result of the use of this Guide or reliance on the information therein.
1.3
DOCUMENT LAYOUT
The Guide has six sections and one appendix:
Section 1 - this section is an introduction. It describes the purpose and layout of the Guide. It also
presents some key definitions used in the RETROFIT PROGRAM.
Section 2 - this section presents a brief overview of the RETROFIT PROGRAM. It also provides a
description of the Engineered Worksheets and their general layout.
Section 3 - this section describes the steps involved in completing the Applicant and Facility Info tab
of the worksheets, which includes the applicant and project contact information, the facility
information, the facility schedule, and the billing data.
Section 4 - this section describes how the operating hours of a measure are to be entered under the
System Schedule tab, as well as how to account for statutory, civic or other holidays, lieu days, or
scheduled shutdowns
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Section 5 - this section discusses the various input data that is to be included on the System Design
Assumptions tab in order to calculate Demand and Energy Savings for commercial lighting,
compressed air systems, variable speed drives on fans, variable speed drives on pumps, and unitary
air-conditioning systems. It also describes the energy and cost data used in calculating the total
project cost.
Section 6 - this section explains the Demand and Energy Savings calculated under the Outputs tab for
each Engineered Worksheet. It also describes the economic benefits that could be derived from the
project and provides quality control (QC) and diagnostics for the LDCs.
Appendix A – this section provides examples of completed Engineered Worksheets and discusses how
energy and demand savings are calculated using case scenarios.
Phrases in italics refer to the different tabs of the Engineered Worksheets. Notes, where available, are
also italicized to emphasize them. Words and phrases in Bold are specific terms used on the worksheets
and are shown in bold in the Guide to help the user quickly find the related information on the
worksheet.
1.4
DEFINITIONS
The following RETROFIT PROGRAM defined terms may help the users of this Guide to better understand
the Guide.
“Demand Savings” means the estimated, determined or actual (as the context may require) reduction
in electricity demand, expressed in kilowatts, obtained as a result of an Engineered Measure or a
Custom Measure and as determined pursuant to an Engineered Worksheet or a Custom Worksheet.
“Energy Savings” means the estimated, determined or actual (as the context may require) electricity
savings achieved over the course of the first year after the completion of a Project, expressed in
kilowatt hours, obtained as a result of an Engineered Measure or a Custom Measure and as
determined pursuant to an Engineered Worksheet or a Custom Worksheet.
“Engineered Measures” means Measures listed on an Engineered Worksheet and that involve the
replacement of inefficient existing equipment with high efficiency equipment.
“Engineered Worksheet” means a worksheet that provides calculations of Energy Savings and
Demand Savings and Participant Incentives for associated Measures in the form provided from time to
time.
“Participant” means a non-residential Distribution Consumer who has (i) submitted an Application
which was approved by the LDC; (ii) agreed to the terms and conditions in the Participant Agreement,
and (iii) satisfied the Eligibility Criteria.
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2)
OVERVIEW
Under the RETROFIT PROGRAM substantial Participant Incentives are available for replacing existing
equipment with high efficiency equipment and for installing new control systems that can improve the
efficiency of businesses’ operational procedures and processes. The program offers three approaches to
achieving energy and peak demand savings: a “Prescriptive” track, an “Engineered” track, and a
“Custom” track.
Under the Prescriptive track an Applicant can select high efficiency retrofit measures from a defined list
that includes a corresponding per-unit incentive. Examples of the types of measures that are possible
under this track are: the retrofit of inefficient equipment, such as lighting, motors, and unitary air
conditioners (A/C), to more efficient equipment. If the proposed retrofit project involves upgrading
existing equipment, the incentive amount that may be available depends on the type, efficiency, and
quantity of the equipment to be installed. To be eligible for the Prescriptive track, the proposed retrofit
measures have to match the requirements for the high efficiency measures on the Prescriptive
Measures List. If, however, a particular measure does not appear on the Prescriptive Measures List, the
Applicant might still be able to proceed using the Engineered track or Custom track.
The Engineered track includes a number of preset calculation worksheets (the Engineered Worksheets)
that estimate the reduction in peak demand and energy that might be available with the installation of
more energy-efficient equipment or solutions. Based on the reductions possible in peak demand and
energy, the worksheets are used in calculating the possible incentive. (Please note that on the
Engineered Worksheets, the Applicant provides the base case assumptions used for calculating the
possible energy and peak demand savings, whereas under the Prescriptive track, the base case
assumptions are provided by the RETROFIT PROGRAM.) In addition, the Engineered track provides the
potential for additional Participant Incentives for the installation of equipment and many consider it a
more straight-forward process than the Custom track, with simplified calculations for estimation of
energy and peak demand savings.
The Custom track is a choice that might be suitable for installation of more complex or innovative
solutions not covered under either the Prescriptive or Engineered track. Technology, equipment, and
system improvements are evaluated on their peak demand and energy-performance. Participant
Incentives can be paid after installation, once the savings have been measured and verified (for large
projects), or once quality assurance and quality control (QA/QC) requirements have been met for (small
projects).
Participant Incentives that may be available for Prescriptive projects are indicated on the Prescriptive
worksheets, which set out the dollar amount per unit installed. For Engineered and Custom track
projects, the Participant Incentives available are:

$400/kW of Demand Savings or $0.05/kWh of Energy Savings for lighting measures (whichever is
higher), to a maximum of 50% of the project costs that are directly related to the procurement
and implementation of the Engineered Measure. More details are found in Section 5.6 – Project
Cost Breakdown.

$800/kW of Demand Savings or $0.10/kWh of Energy Savings for non-lighting measures
(whichever is higher) including lighting controls, to a maximum of 50% of the project costs.
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2.1
THE RETROFIT ENGINEERED WORKSHEETS
There are seven worksheets available under the Engineered track of the RETROFIT PROGRAM
(https://www.saveonenergy.ca/Business/Program-Overviews/Retrofit-for-Commercial/RelevantDocuments.aspx):

Combined Commercial Lighting Engineered Worksheet

Lighting Controls Engineered Worksheet

Compressed Air Engineered Worksheet

Variable Speed Drive (VSD) Compressed Air Engineered Worksheet

Variable Speed Drive (VSD) on Fan Engineered Worksheet

Variable Speed Drive (VSD) on Pump Engineered Worksheet

Unitary A/C Engineered Worksheet
These Engineered Worksheets are used to estimate the Demand Savings and Energy Savings for the
purpose of calculating the Participant Incentives that may be available as a result of implementing
Conservation Demand Management (CDM) measures. The Engineered Worksheets are not meant to be,
and should not be, used as design tools.
2.2
ENGINEERED WORKSHEET LAYOUT
The Engineered Worksheets follow a similar layout, with an Introduction tab and the following four
major tabs:

Applicant and Facility Information

System Schedule1

System Design Assumptions

Outputs
As well, most of the worksheets have either a Reference tab or a set of additional tabs containing
relevant technical specifications.
1
For Unitary A/C Engineered Worksheet, the System Schedule is found on the System Design Assumptions tab.
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2.2.1
Types of Cells
There are three types of cells used in the worksheets input cells, output cells, and optional cells:
Input cells  You can enter information in these cells in text or numerical format.
Information entered into these cells is used in calculating potential Energy and Demand
Savings, Participant Incentives, and the project economics.
Output cells  You cannot enter information into these cells. These cells show the
calculated potential Energy and Demand Savings, Participant Incentives and project
economics. In the various Commercial Lighting Engineered Worksheets they also show
calculated potential lighting level output based on information you may provide in
optional cells (see below).
Optional cells  On the various Commercial Lighting Engineered Worksheets you can
enter numerical information in these cells. The cells are used in calculating the estimate
of: a room’s cavity ratio, average illuminance in the workplane, estimated usable lumens
per watt, and percent change in workplane illuminance.
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3)
THE APPLICANT AND FACILITY INFORMATION TAB
The Applicant and Facility Information tab collects relevant information about the Applicant, including
their primary project contact details, facility information, facility schedule, and the facility’s electricity
billing data. Once the Applicant and Facility Information tab has been completed, the Engineered
Worksheet may be saved and used for multiple applications, changing only the information under the
System Schedule and System Design Assumptions tabs. (Given the ability to save and re-use this
information, to prevent accidentally overwriting it, it is recommended to save a separate master copy of
the worksheet.)
3.1
APPLICANT AND PROJECT CONTACT INFORMATION
Note: If the Applicant has completed and submitted an Application for the RETROFIT PROGRAM using
the online application process via the saveONenergy website (www.saveonenergy.ca), then it is
not necessary to complete the Applicant and Project Contact Information section. However,
since the worksheet will be uploaded as supporting documentation for an application using the
online application process, we recommend naming of the worksheet in a manner that is suitable
for the RETROFIT PROGRAM.
Contact details for the Applicant Representative or Primary Project Contact person are entered in the
appropriate cells of the worksheet as shown in Figures 1 and 2. The Applicant Representative or Primary
Contact person may need to be contacted for inquiries relating to the information provided on the
worksheet or regarding the project.
Figure 1 – Applicant Information
Figure 2  Applicant Representative/Project Contact Information
3.2
FACILITY INFORMATION
Facility information, such as the Building Name, Address, Building/Property Type and Gross Facility Floor
Area in square feet, is entered in the appropriate cells as shown in Figure 3. This information is for the
individual who may be tasked with doing pre- and post-project site visits.
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Figure 3  Facility Information
The Applicant selects the building/property type from one of the 10 listed choices in the dropdown list:
Office, Retail, Health Care, Multi-Residential, Warehouse, Agri-business, Hospitality, Educational,
Industrial, and Other.
Notes:
1) Select “Other” from the dropdown list if the building/property type is not one of specific types and
then specify the building/property type in the cell next to the one that reads “If ‘Other’, indicate
type”.
2) If the Building/Property Type has mixed uses, indicate the percentage of floor space allocated to
each of the uses of the building (Figure 3, for example, shows a 30,000 sq. foot Health Care
property in which 80% of the floor area is used for Health Care and 20% for Office).
3) Indicate the Type of Project being applied for by selecting from the drop downlist whether it is
Planned Replacement, Unexpected Replacement, New Equipment for new process or Expansion of
Operations, or Efficiency Upgrade.
3.3
FACILITY SCHEDULE
The typical operating hours of the whole facility during weekdays, weekends, and holidays are entered
in the Facility Schedule section, as shown in Figure 4.
Note: This information refers to the overall facility schedule, not the operating hours of the equipment,
which is entered separately under the System Schedule tab.
Figure 4  Facility Schedule
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3.4
BILLING DATA
The monthly electricity consumption and peak demand for the last 12 months are entered in the Billing
Data section. This information is used to discern the energy consumption pattern of the building.
Electricity Consumption is a measure of how much electricity is consumed in kilowatt hours (kWh) for
the building, while Peak Demand is a measure of the highest level of demand in kilowatts (kW) or
kilovolt-amperes (kVA) as measured during the billing period.2 Data to be input on this section of the
worksheet can usually be found on the facility’s hydro bill and should be entered in the appropriate cells
as shown in Figure 5.
Figure 5  Billing Data
Note: If the utility’s billing cycle covers two months, enter the monthly data under the month where the
majority of the billing period occurs. For example, Electricity Consumption and Peak Demand
data for a billing cycle of March 14 – April 13 would be entered under the month of March.
Once the data is entered, the Engineered Worksheet will automatically compute the total electricity
consumption and determine the maximum electricity consumption and peak demand over the 12
month period.
2
Independent Electricity System Operator, “A Guide to Electricity Charges for Business”,
http://www.ieso.ca/imoweb/siteshared/electricity_charges.asp?sid=md
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4)
THE SYSTEM SCHEDULE TAB
The operating hours for the equipment or measure (for example, high bay lighting, variable speed drive,
compressed air system) are entered in the System Schedule tab of the Engineered Worksheet using the
24 hour 7 day table as shown in Figure 6. If the equipment is scheduled to operate for a certain hour,
enter “1” and if the equipment is not scheduled to operate for a certain hour, enter “0”.
As shown in Figure 6, the cells within this table will change to purple when “1” is entered, indicating that
the equipment is in operation. The information on this table is used to estimate the total annual
operating hours for the equipment and serves as the basis for energy calculations. If the equipment
operates for only part of an hour (for example, it starts working at 9:30 a.m.), it is recommended to
show the full hour of operation.
Figure 6  Zone Operating Hours for the Interior Lighting
The total annual operating hours can be further adjusted by the number of days the equipment is not
operational due to statutory, civic or other holidays, lieu days, or scheduled shutdowns. Under the
System Schedule tab there is a chart showing 11 Ontario civic and statutory holidays. As can be seen in
Figure 7, the holiday information is used to pre-populate the table located just to the left of the list of
holidays.
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Figure 7  Adjustments Due to Holidays and Scheduled Shutdowns
Note: The figures presented in the table to the left of the list of Ontario holidays can be further
adjusted to reflect the actual operation schedule at the facility. For example, if the equipment at
the facility is on during Canada Day but not operational for 3 days during the month of February,
as shown in Figure 8, the user would reduce the pre-populated number in the cell for July by 1
day, and increase the pre-populated number in the cell for February by 3 days.
Figure 8 – Pre-Populated versus Adjusted Days
The Engineered Worksheet automatically computes the total annual operating hours for the equipment
based on the weekdays, weekends, and holiday schedule entered by the Applicant. A summary of these
operating hours are displayed as shown in Figure 9. In this summary table, the typical weekly number of
operating hours for the equipment based on the schedule (excluding holidays) is also shown.
Figure 9  Summary of Operating Hours for the Interior Lighting in a Specific Zone
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5)
THE SYSTEM DESIGN ASSUMPTIONS TAB
The System Design Assumptions tab collects information on input assumptions (for example, wattages,
operating pressure, pump curve, and so on) for the base case and retrofit systems, operating profiles,
economic value assumptions, and project cost breakdown. Because the information collected under the
System Design Assumptions tab is relevant to the particular worksheet, the different worksheets are
discussed in the following subsections:
5.1 Combined Commercial Lighting Engineered Worksheets
5.2 Lighting Controls Engineered Worksheet
5.3 Compressed Air Engineered Worksheet
5.4 VSD Compressed Air Engineered Worksheet
5.5 VSD on Fans Engineered Worksheet
5.6 VSD on Pumps Engineered Worksheet
5.7 Unitary Air Conditioning (A/C) Engineered Worksheet
Note: Applicants are encouraged to gather all relevant technical and economic input assumptions they
will need before they begin filling in the System Design Assumptions tab of the worksheet.
5.1
COMBINED COMMERCIAL LIGHTING ENGINEERED WORKSHEETS
There are various types of Commercial Lighting Engineered applications that can be submitted under the
Combined Lighting Engineered Worksheet

Commercial Interior Lighting;

Commercial High Bay Lighting; and

Commercial Directional Lighting.

Commercial Exterior Lighting

Commercial Specialized Lighting

Commercial Architectural Lighting
Note: The Combined Lighting Engineered Worksheet has a System Design Assumptions tab under
which data is collected regarding the base case and the retrofit lighting systems, as well as zone
information. Under this tab there are also cells that are highlighted in purple that are not
mandatory but that may help the user assess the lighting levels of the base case and retrofit
lighting systems.
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5.1.1
Base Case and Retrofit Lighting System
Under the Base Case Lighting System and Retrofit Lighting System sections, the technical specifications
for the existing (base case) and retrofit commercial lighting system, respectively, are entered. The
required technical specifications can include: the Type of Fixture, Other Types of Fixtures, Lamp Type,
Nominal Lamp Wattage, Number of Fixtures, Lamps per Fixture, and Input Wattage per Fixture. This
information can be sourced from existing fixture/ballast or manufacturers’ cut sheets, as well as from
information under the Reference tabs included in the Engineered Worksheet. This information should be
entered for both the base case and retrofit lighting system. Figures 10 and 11 show examples of how
this information might appear on a worksheet.
Figure 10 – Base Case Lighting System
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Figure 11 – Retrofit Lighting System
The paragraphs that follow provide brief description of the rows in these charts.

Type of Fixture  The type of fixture can be selected from a dropdown list. Table 1 lists the
different types of fixtures that can be selected in each of the Combined Lighting Engineered
Worksheets. The configurations of each of these fixtures are located under the Commercial CU
Tables tab. Other types of fixtures not included in the dropdown list can be entered in cells on the
“Other Types of Fixture” row.

Lamp Type  This cell is used to identify the type, size, and rated wattage of the existing lamps.
Examples include 4’ T8 (4 ft linear T8 fluorescent lamps), MH (metal halide), or PAR 38 for halogen
or LED lamps.
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
Nominal Lamp Wattage  This is the wattage at which a lamp is designed to operate.3 It is the
lamp wattage supplied by lamp manufacturers.

Number of Fixtures and Lamps per Fixture  These cells are used to indicate the number of
fixtures and the number of lamps in a fixture that will be replaced in the specified zone. The
worksheet can accommodate up to 20 different types of fixtures. (If there are more than 20
fixtures, fill out another worksheet.)
5.1.2
Base Case and Retrofit Power Input
As shown in Figures 10 and 11, the Base Case Power Input and Retrofit Power Input sections are where
the Input Watts per Fixture of the existing and retrofit commercial lighting system are entered. The
Input Watts per Fixture may differ from the Nominal Lamp Wattage. Once the Input Watts per Fixture is
entered, the Total Connected Lighting Power (kW) is automatically calculated by the Engineered
Worksheet.

Input Watts Per Fixture  This is the total wattage required by both the ballast and the lamps in a
luminaire or fixture that depends on the number of lamps, ballast type, and ballast factor.
Reference input wattages are available under the relevant Reference tab or from manufacturers’
cut sheets.
Table 1 – Types of Fixtures for the Commercial Lighting Engineered Worksheets (from the worksheet
dropdown lists)
Commercial Interior Lighting
Commercial High Bay Lighting Commercial Directional
Lighting
Baffled
Parabolic
Recessed
Troffer
Clear Acrylic Open
Halogen Flood
Acrylic Lens
Troffer
Clear Acrylic Enclosed
Incandescent
Acrylic Wrap
Spun
Aluminum
Reflector
Compact
Fluorescent
Indirect Basket
Linear
Fluorescent
LED Bulb
3
Test Procedures Regarding Fluorescent Lamp Ballasts.
http://www1.eere.energy.gov/buildings/appliance_standards/residential/pdfs/10_cfr_430q.pdf
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The information in the cells in the remaining rows of the Base Case and Retrofit tables are optional for
the user to enter data. Whether these cells are populated does not affect the computation of the Energy
and Demand Savings. However, providing information in these optional cells will help determine lighting
level metrics, such as the average illuminance in the workplace and usable lumens per watt, which are
shown on the Base Case Light Output tables on the worksheets. It also determines the percentage
change (increase or decrease) in workplace illuminance due to the lighting retrofit. The lighting level
results from using the optional cells are meant to guide users on the impact of the lighting retrofit. The
light level results are not meant to be used as design tools.
5.2
LIGHTING CONTROLS ENGINEERED WORKSHEET
5.2.1
Lighting Controls Overview
The energy performance of lighting controls is defined by the lighting installed, the control type, amount
of daylight present, and by the users behaviour. The savings a particular lighting control achieves is
dependent on how often the light can be turned off (or dimmed) which is in-turn defined by the
movement pattern (e.g. occupancy) through the space.
5.2.2
Lighting System Operating Schedule
The operating hours for the lighting system in the facility are entered in the Lighting System Operating
Schedule section of the Engineered Worksheet using the 24 hour 7 day table as shown in Figure 12. If
there is only one operating schedule for the whole year, enter the schedule only under Season 1. If
there is more than one operating schedule for the year (e.g. different On Time and Off Time for the
cooling months) as in the case of some schools, enter the schedule under Season 2 and Season 3. To
ensure that the number of operating hours is properly inputted, when entering dates and time it is
important to always use the drop down menus.
Figure 12 - Lighting System Operating Schedule
The number of holidays in the facility’s calendar year is also inputted and considered in the computation
of the annual operating hours.
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5.2.3
Space Information
In the Space Information section, information about the applicable space type and room dimensions is
entered as shown in Figure 13. The Engineered Worksheet can be used for the following space type:
private office, open office, classroom, conference/meeting room, warehouse, cafeteria, gymnasium,
changeroom/restroom and storage room. The area of the space is automatically calculated.
Figure 13 - Space Information
5.2.4
Lighting Information
To appropriately define the lighting system that is being operated, the user is required to describe the
lighting fixtures (e.g. no. of lamps, fixture type) that are to be controlled within the space. For each
fixture, the total input watts and the number of fixtures within the space are entered. This defines the
base power consumption for the lighting control. The user is also asked to provide the percentage that
the lamps may be dimmed to. Some lighting types such as high intensity discharge (HID) lamps may only
be dimmed to a percentage of their initial output rather than allowing the controller to completely turn
them off. This defines a percentage of the power which is not controlled via the lighting controls.
Figure 14 - Lighting Information
5.2.5
Daylighting Information
If daylight sensors are installed, more information is necessary and entered into the Daylighting
Information section as shown on Figure 15. The user is asked to select the type of daylight control
(on/off, stepped dimming, fully modulating dimming). With on/off control, the daylight sensor turns the
light off when there is adequate daylight (OFF/100%). Stepped dimming control dims the light to track
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the available natural light via a series of output levels (e.g., OFF/30%/60%/100%). Fully modulating
dimming dims the light proportionally to the level of natural light available (OFF to 100%).
Figure 15 - Lighting Information
Information about the amount of daylight available in the space is also provided through an exterior
window to wall ratio and an estimation of the window tint. The window to wall ratio represents the
area of the windows over the exterior wall surface area. For example: a window to wall ratio of 40
indicates that 40% of the wall area is window with the remaining 60% as wall.
Window tint is viewed from the building exterior. Clear windows offer almost no obstruction to viewing
the interior. Light tints offer more obstruction and are often green in colour. Dark tints are reflective
and often blue, bronze, or gray. The window tints correspond to different levels of window visible
transmittance as listed below the representative photographs shown in the worksheet. Clear, light and
dart tint correspond to visible transmittance of 0.8, 0.6 and 0.4, respectively.
5.3
COMPRESSED AIR ENGINEERED WORKSHEET
The Compressed Air Engineered Worksheet uses information entered by the Applicant to evaluate the
base case and the energy efficient case for a series of potential improvements to a compressed air
system. It is expected that the user will have a good understanding about compressed air system
components, and the “cause and effect” relationship between potential equipment and operational
changes and corresponding energy consumption.
The System Design Assumptions tab for the Compressed Air Engineered Worksheet is divided into seven
(7) tabs. Two (2) tabs, namely Compressor Inventory and Pipe Volume & Pressure Test collects
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information on the existing air compressors and their main distribution pipes and receiver tanks,
respectively. A Summary tab has been added to provide a summary on the measures, energy impact,
project economics and incentives. The last four (4) tabs collect information on the base case and the
energy efficient case for a series of potential improvements to a compressed air system, such as:

Measure 1 - Reducing leaks

Measure 2 - Reduce pressure

Measure 3 - Using an energy efficient refrigerant air dryer (cycling, non-cycling and desiccant)

Measure 4 - Using zero loss air drains
The Engineered Worksheet contains two (2) additional tabs, namely, a Navigation tab and a Start Here
tab. The Navigation tab provides information on the different tabs of the worksheet and explains how
to navigate the different tabs. The Start Here tab is an important tab and users are instructed to study
this carefully.
5.3.1
Compressed Air Systems Overview
To provide context, a brief description of compressed air systems is useful.
Compressed air systems are comprised of several major sub-systems and many sub-components and,
consequently, the energy efficiency results from multiple measures are not necessarily additive. Major
sub-systems include: the compressor, prime mover, controls, treatment equipment and accessories, and
the distribution system. The compressor is the mechanical device that takes in ambient air and increases
its pressure. The prime mover powers the compressor. Controls serve to regulate the amount of
compressed air being produced. Treatment equipment removes contaminants from the compressed air
and accessories keep the system operating properly. Distribution systems are analogous to wiring in the
electrical world they transport compressed air to where it is needed. Compressed air storage can also
serve to improve system performance and efficiency.
When analyzing a compressed air system, it is useful to start by sketching a block diagram. Note the
number and location of each air compressor and their designated names (for example, maintenance
shop compressor) along with each compressor’s make and model, motor size (horsepower), estimated
motor age, motor speed, whether it is a standard or premium efficiency motor, and motor designation
(ODP or TEFC).
Record details about other auxiliary equipment, especially:
1) air dryers (refrigerated, desiccant, or none), and
2) wet and dry air receivers – note the nameplate capacity or estimate the approximate volume
(cubic feet) for each receiver.
Trace the entire length of the air compressor distribution piping, noting the pipe diameter (in inches) for
the main header and the overall length (in feet) of the distribution piping system. Engineering judgment
will likely be needed to convert smaller diameter or smaller length pipes to equivalent main header
dimensions.
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5.3.2
Start Here Tab
The Start Here tab contains a checklist of scenarios to determine if the project qualifies to use the
Engineered Worksheet as well as a list of information or data to have on hand when completing it. The
pre-qualifying checklist includes the following scenarios:

The largest individual air compressor in the system is not more than 350 HP.

There are no more than five (5) fixed speed positive displacement (rotary screw or piston)
compressors in the system.

The typical system operating air pressure is between 70 to 150 psig.

There are no variable speed air compressors under evaluation (Note: for a VSD compressor, use
the IESO's VSD Compressed Air Worksheet)

There is at least 1 hour available when the compressor(s) can be operated to perform the Pressure
Decay Test (Refer to Guide for details)

The compressor(s) are all connected to the same distribution system, which operate at a common
discharge pressure.

This compressed air system is used for general plant air or building controls.

This application does not involve retrofitting an existing compressor motor with a premium
efficiency motor (Note: for motor changes, use the IESO's prescriptive application for motors)

If applying for incentive to reduce air leaks, Applicant must agree to implement an air leak
management program for a minimum period acceptable to the IESO.

If applying for incentive to reduce air discharge pressure, Applicant must agree to implement an
air leak management program for a minimum period acceptable to the IESO.

This worksheet is designed for MS Excel 2007. User acknowledges that it may not be fully
compatible with earlier or later versions of MS Excel.
At the end of the list of scenarios, the user selects either "Yes" or "No". By selecting "Yes", the user is
certifying that all of the above-stated requirements and pre-qualifications are met. By selecting "No",
the user is certifying that one or more of the above-stated requirements and pre-qualifications is not
met and that the Engineered Worksheet should not be used. If the applicant user still wants to apply for
incentives, the RETROFIT PROGRAM's Custom Track can be explored. Figure 16 shows the checklist of
different pre-qualification scenarios.
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Figure 16 - List of Pre-Qualifiers for the Use of the Engineered Worksheet
At the Start Here tab, it is important to indicate the compressed air efficiency measures that the users
are applying for as shown in Figure 17. This triggers the estimation of the savings in the respective
measure tabs of the worksheet. If a "No" is selected, savings will appear as zero.
Figure 17 - Indicate Intention to Apply
At the bottom part of the Start Here tab, a list of information and compressed air data needed to
complete the Engineered Worksheet is provided. See Figure 18 for this list of information and data.
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Figure 18 - Information Required Before Completing the Worksheet
Compressor Inventory
The Engineered Worksheet relies on information provided by the Compressed Air and Gas Institute
(CAGI) for air compressors. CAGI is an independent organization with membership from major air
compressor and refrigerant dryer vendors and other stakeholders from the compressed air community.
It has developed standard data sheets completed by manufacturers of rotary compressors from 25 - 200
hp, and standalone refrigerated compressed air dryers from 200 - 1000 scfm4. Participation is voluntary
and is open to all equipment manufacturers, whether they are a CAGI member or not. The use of CAGI
Data Sheets has been incorporated into the Compressed Air Engineered Worksheet calculation process
as it provides an open, transparent and industry-accepted method to evaluate different compressors
and/or refrigerant dryers. For more detailed information about CAGI and its Data Sheets, refer to
section 5.4.1.
The Compressor Inventory tab collects information on the existing air compressors using the CAGI Data
Sheets and typical operating parameters as well as information on the cost of power which will be used
in the economic analysis of the project.
The first section of the Compressor Inventory tab as shown in Figure 19 asks for the blended cost of
power ($/kWh) and the estimated monthly peak demand unit cost ($/kW) which can be obtained from
4
In practice, some manufacturers publish for equipment sizes larger or smaller than the CAGI limits. The
Engineered Worksheet can evaluate individual rotary screw compressors up to 350 hp and refrigerant dryers up to
2000 scfm.
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the utility bill. The compressed air system operating hours per year is automatically estimated from the
System Schedule tab.
Figure 19 - Annual Operating Hours and Unit Cost of Power
The Air Compressors section requires data from the CAGI Data Sheets and from typical operating data of
the compressors as shown in Figure 20. Up to five air compressors can be included in the engineered
worksheet. Use the AC#1 column to input data on the largest compressor. Continue using the columns
to the right for the next largest compressor and so on.
Figure 20- Air Compressors Input Data
As shown in Figure 20 above, the required data from the CAGI Data Sheets are indicated in box
numbers. For example, the Rated Capacity at Full Load Operating Pressure in actual cubic feet per min
(acfm) can be found in Box No. 3 from the CAGI Data Sheet for the selected compressor. In addition, the
user is required to provide an estimate of the Typical Percent of Full Load Operating Point (F.L.) and
Typical Operating Pressure for each compressor and to provide an explanation in the space provided in
the worksheet about the methods used as the basis to estimate these two parameters. This explanation
will be used by the Technical Reviewer. Not providing an explanation will cause the worksheet to
make the energy savings and incentive amounts zero.
If there are more than one compressor, the input parameters will either be summed up or averaged as
indicated in the last column in green of the Air Compressors section. The Operating Flow will
automatically be estimated for each compressor using the following equation:
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Operating
Flow (cfm)
=
Rated Capacity at Full Load
Operating Pressure (acfm)
x
Typical Percent of Full Load
Operating Point (%)
100
The Power Demand (kW) and Annual Energy Consumption (kWh) for Air Compressors at Typical
Operating Level are summation of the power demand and annual energy consumption at typical
operating level of each compressor as shown in the following equations:
Power Demand at Typical
Operating Level (kW)
=
Power Demand at
Operating Flow (kW)
Pressure
Adjustment Factor
x
Power demand at operating flow (kW) is extrapolated using a linear relationship between air flow and
input power of the compressor. The CAGI Data Sheets provide the rated capacity at full load operating
pressure for the air flow and the total package input power at both zero flow and at the rated capacity
air flow. The Pressure Adjustment Factor assumes a 0.5% increase or decrease in power demand
depending on the difference between the full load operating pressure and the typical operating
pressure.
The annual energy consumption at typical operating level for each compressor is estimated as follows:
Energy Consumption of
Compressor at Operating
Level (kWh)
=
Power Demand at
Typical Operating
Level (kW)
x
Annual Operating
Hours (hrs)
The annual energy cost of compressors is estimated by applying the blended cost of power to the total
annual energy consumption of compressors.
Pipe Pressure and Volume Tests
It is assumed that the user of the engineered worksheet is familiar with the practical and safety aspects
of conducting a pressure decay test to estimate air leaks. Air leaks are estimated using the air
distribution volume which is in turn estimated using dimensional data for pipes and storage tanks in
conjunction with pressure decay testing.
Air leaks are determined through pressure decay tests. The purpose of such tests is to determine the
approximate amount of leakage. The best time to perform such tests is during a non-production period,
such as over a weekend. During a non-production period the compressed air system is permitted to
pressurize until the compressor begins modulating. Under normal circumstances, only one air
compressor (typically the largest) needs to operate.
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Pressure decay tests are conducted as follows:

The (higher) initial pressure is measured when the compressor is unloaded and the (lower) final
pressure is when the compressor loads.

The time for the pressure to decay from high to low can be considered equivalent to the time
between loading and unloading.
Using a stopwatch, the observer measures the time interval between compressor loading and
unloading, in seconds. Simultaneously, the load and unload discharge pressure, as shown on the air
compressor pressure gauge or system pressure gauge, is noted. The time is expressed in seconds (for
example, 4 minutes and 20 seconds = 260 seconds).
The Pipe Pressure and Volume Test tab consists of two sections, namely, the System Volume of Main
Distribution Pipes and Receiver Tanks section and the Pressure Decay Test section. The first section
requires the user to include data about the distribution pipes having the two largest pipe diameter
dimensions as shown in Figure 21. If there is only one pipe and no receiver tanks, only the largest
diameter distribution pipe dimensions should to be entered. Use technical judgment to adjust for
equivalent pipe diameter and length if there are more than two sizes of distribution pipes or for complex
air distribution configurations. Up to five different dimensioned receiver tanks can be entered as well as
the number of similar tanks for some situations.
Figure 21 - System Volume of Main Distribution Pipes and Receiver Tanks
The engineered worksheet automatically calculates the approximate internal volume of the air header
supply and receiver storage tanks based on the given diameters and lengths provided by the user.
On the Pressure Decay Test section, the average of five (5) pressure decay tests is used to estimate the
air leakage as shown in Figure 22. The starting and ending pressures in psig recorded during the testing
and time for the pressure decay in seconds are entered.
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Figure 22 - Pressure Decay Test
The engineered worksheet will reject some incorrect entries. For example, if the ending pressure is
higher than the starting pressure, or if the starting pressure is higher than the capability of the
compressor. If there are less than three values entered for a particular test result, a warning message
will appear at the bottom of the pressure decay test field.
5.3.3
Measure 1 – Reduce Air Leakage
Leaks can be a significant source of wasted energy in an industrial compressed air system, sometimes
representing 20-30% losses of a compressor’s output. They can also contribute to other operating
losses. Leaks typically cause a drop in system pressure, which can mean air tools function less efficiently,
adversely affecting production. Finally, leaks can contribute to the addition of unnecessary compressors
or compressor capacity. Reducing air leakage can not only improve the operating performance of the
compressor, it can also reduce energy consumption.
The 1 Reduce Leaks tab requires the following inputs to estimate the annual energy savings and energy
costs as shown in Figure 23:

First, the user must toggle the response from "No" to "Yes" regarding commitment to implement
a sustained air leakage management program. It is to be noted that leaving the default “No”
response will result in zero energy savings and zero potential incentive.

Second, the user must enter a target percent for maximum allowable air leaks. Most industrial
facilities consider 10% air leakage to be a reasonable amount.

Third, the user must enter economic parameters about the cost to repair and maintain that air
leaks at the targeted amount.
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Figure 23 - Reduce Air Leaks and Non-Productive Compressed Air Use
The annual energy savings attributed to reducing air leaks is estimated from the difference of the
Estimated Air Leaks and Non-Productive Air Losses as Percentage of Normal Compressor Flow and the
Percent Target for Maximum Allowable Air Leaks and Non-Productive Air Use. The Estimated Air Leaks
and Non-Productive Air Losses as Percentage of Normal Compressor Flow is calculated as the
percentage of the Estimated Leakage and Non-Productive Air Losses (at 100% Compressor Flow Output)
to the total operating flow. The following equations are used to calculate the values in green in the 1
Reduce Leaks tab:
Estimated Leakage
at 100% Compressor =
Flow Output (cfm)
1.25
x
Total Volume of
Piping and
Receivers (ft3)
Estimated Air Leaks as Percentage of
Normal Compressor Flow (%)
Estimated Annual Energy
Losses through Air Leaks
(kWh)
Estimated Air Leaks at
Target Leak Level (cfm)
=
=
=
x
Starting
Ending
Pressure - Pressure
(psig)
(psig)
Decay Time (min) x
14.7 psig
Estimated Leakage at 100%
Compressor Flow Output (cfm)
x
x
60
sec/min
100
Total Operating Flow (cfm)
Annual Energy Consumption
for Air Compressors at Typical
Operating Level (kWh)
x
Estimated Air Leaks as
Percentage of Normal
Compressor Flow (%)
Estimated Leakage at 100%
Target Allowable
x
Compressor Flow Output (cfm)
Leaks (%)
Estimated Air Leaks as Percentage of Normal Compressor
Flow (%)
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Required Reduction in Air
Leaks to Meet Target (cfm)
Annual Energy
Savings (kWh)
=
=
Estimated Air
Leaks (%)
Annual Demand
Savings (kW)
Estimated Leakage at 100%
Compressor Flow Output (cfm)
-
Target
Allowable Leaks
(%)
=
x
-
Estimated Air Leaks at
Target Leak Level (cfm)
Annual Energy Consumption
for Air Compressors at Typical
Operating Level (kWh)
Annual Energy Savings (kWh)
Annual Operating Hours (hours)
Since there exists some uncertainty on energy savings from air leaks, a “permanence factor” is applied
to the energy and demand savings.
The annual cost of air leaks as well as annual cost savings are automatically calculated by the engineered
worksheet.
5.3.4
Measure 2 – Reduce Discharge Pressure
As a rule of thumb, when air compressor discharge pressure is reduced by 2 pounds per square inch
gauge (psig), this generally results in compressed air energy savings equivalent to 1% of the total
compressor output.
During a site visit, it is prudent to ask plant personnel if the overall plant air pressure can be reduced
without impacting plant and equipment operation and if so, what a reasonable air pressure target value
might be.
The 2 Reduce Pressure tab requires the following inputs to estimate the annual energy savings and
energy costs as shown in Figure 23:

First, the user must toggle the response from "No" to "Yes" regarding commitment to implement
a sustained system pressure reduction management program. It is to be noted that leaving the
default “No” response will result in zero energy savings and zero potential incentive.

Second, the user must enter a target average air discharge pressure.

Third, the user must enter economic parameters about the cost to maintain target average air
discharge pressure.
The annual energy savings attributed to reducing discharge pressure is estimated based on the
difference of the average existing typical operating pressure of the compressor and the targeted lower
discharge pressure as shown below.
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Annual
Energy
Savings
(kWh)
=
Average normal
operating
discharge
pressure (psig)
-
Target
pressure
(psig)
x
Annual Energy
Consumption of
Compressors
(kWh)
-
Annual Energy
Savings from
Reduced Leaks
(kWh)
x
0.005
Demand savings is estimated as follows:
Annual Demand
Savings (kW)
=
Annual Energy Savings (kWh)
Annual Operating Hours (hours)
Similar to Measure 1, there exists some uncertainty on energy savings from reducing discharge pressure
and hence, a “permanence factor” is applied to the energy and demand savings.
5.3.5
Measure 3 – Energy Efficient Dryer
In most manufacturing facilities, dryers are used to control moisture in the compressed air system. A
potential energy saving opportunity is to use a dryer that has a dew point (degree of moisture removal)
that is appropriate for how dry the air is required to be for the process. (The lower the dew point, the
more energy is used.) For example, a refrigerated dryer can often be used instead of a desiccant dryer
for general plant use. A desiccant dryer, on the other hand, is only required if the air needs to have a
very low dew point, for example in a pneumatic control system. For desiccant dyers, the engineered
worksheet assumes a power consumption of 2.5 kW per 100 scfm.
The 3 Air Dryer tab has four sections, the confirmatory section, the existing and the proposed air dryers
section, a dryer technical summary and the economics section.
If the explanation for the flow and pressure estimation methods was provided in the Compressor
Inventory tab, an “OK” message will appear. If the explanation was not provided, a warning message
will appear instead and all of the dryer energy calculations will default to zero.
The confirmatory section asks the user if the required dew point is to be above 32°F (0°C) as shown in
Figure 24. If the response is YES, then the project is eligible to convert from a desiccant dryer to a
refrigerant dryer or from a refrigerant dryer to a more efficient refrigerant dryer. If the required
moisture dew point is less than 32°F, then a desiccant dryer should be used and refrigerant dryers
should not be considered.
Figure 24 - Confirmatory Section for Required Dew Point
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In the next section, up to five (5) existing and five (5) new dryers can be included in the worksheet. The
user must allocate a portion of the total air flow for Dryer#1 as shown in Figure 25. This quantity may be
based on actual measurements or good judgment.
Figure 25 - Existing and Proposed Air Dryers
If it is determined that the required dew point is above 32°F and the existing dryer is a desiccant dryer,
the user may omit completing the remaining columns in the Existing Dryer panel and to only complete
the Proposed Dryer panel to the right. However, if the existing dryer is a refrigerant dryer then the user
should continue completing both the Existing and the Proposed Dryer panels.
The subsequent calculation for the power requirement of the Existing and the Proposed Dryer is based
on the allocated air flow for the dryer and information from the CAGI data sheets for both full flow and
10% flow conditions assuming a linear relationship between flow and power. Any untreated air quantity
will be shown at the bottom of the panel. It is to be noted that there may be an overall mismatch
between total compressor capacity and total dryer capacity and hence, the user must make the choice
for the appropriate dryer size and configuration. The process is repeated for the next dryers until the
untreated amount air turns zero.
For situations where a CAGI data sheet is not available the user may use data points from similar air
dryer from the same manufacturer. Alternatively an estimation for the CAGI missing data points subject
to providing a separate and detailed explanation for the project reviewer be provided.
For easy reference, a Dryer Technical Summary has been provided after the Existing and Proposed
Dryers section as shown in Figure 26. There will also be some guidance notes appearing after the
summary section.
At the last section where eligible costs are entered, the overall energy and demand savings are shown.
In some situations, depending on the dryer selection and configuration, there can be a net increase
(rather than decrease) with the energy consumption of the dryers. The engineered worksheet will
convert negative savings numbers to zero.
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Figure 26 - Existing and Proposed Air Dryers
5.3.6
Measure 4 – Zero Loss Drains Tab
For the 4 Zero Loss Air Drains tab, the user will indicate the total number of wet drains, and the existing
number of zero loss air drains as shown in Figure 27. The engineered worksheet will then calculate the
eligible number of drains that may be converted. The user will then enter the desired number of drains
together with the cost per drain and the engineered worksheet will compute for the capital cost using
some prescriptive input assumptions. The user may also enter other installation and miscellaneous
implementation cost.
Figure 27 - Use of Zero Loss Condensate Drains
5.3.7
Summary of Measures, Energy Impact, Project Economics & Incentives
After all necessary information has been entered; the Engineered Worksheet will calculate the
Estimated Energy Savings (Permanent and Non-Permanent) from the difference between the Estimated
Base Case and Estimated Net New Annual Energy Consumption. It will then compute the Estimated Base
Case Peak Demand and Estimated Proposed Case Peak Demand (while operating) by dividing the Annual
Energy Consumption by the annual operating hours for both the base case and proposed case.
Estimated Demand Reduction, in turn, is calculated by getting the difference between the base and
proposed case. It shows how much energy is expected to be saved in Figure 28.
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Figure 28 – Annual Savings and Economics
5.3.8
Summary of Underlying Calculation and Assumptions
The following equations are used to calculate the Base Case Energy and net CDM5 Case Energy
consumption in kWh.
Base Case Energy:
Total
Compressor
Output (cfm)
n
=

Motor Rated
Power (bhp)
x
n=1
Compressor
Efficiency Factor
(cfm/hp)
x
% Loading
of
Compressor
where n represents the number of compressors included in the Retrofit Application
Total Energy
Consumption of
Compressors (kWh)
Energy
Consumption of
Dryer (kWh)
=
=
Total Compressor
Output (cfm)
Average Compressor
Efficiency Factor (cfm/hp)
Total Compressor
Output (cfm)
x
0.746
kW/hp
x
Energy Factor
(kWh per 100 cfm)
x
x
Annual
Operating
Hours (hrs)
Annual
Operating
Hours (hrs)
The total energy consumption for the base case is:
Total Energy
Consumption (kWhb)
=
Total Energy Consumption
of Compressors (kWh)
+
Energy Consumption
of Dryer (kWh)
The base case peak demand is:
5
Conservation and Demand Management
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Total Peak Demand (kWb)
=
Total Energy Consumption (kWhb)
Annual Operating Hours (hrs)
Net CDM Case Energy:
Measure 1 – Reduce Air Leakage
Air leaks at target leak
level (cfm)
Amount of air leaks to
be reduced (cfm)
Annual Energy
Savings (kWh)
=
=
=
% target allowable
leak level
Air Leaks at 100%
Compressor Output (cfm)
Amount of air leaks to be
reduced (cfm)
Average Compressor Efficiency
Factor (cfm/hp)
Total Compressor
Output (cfm)
x
x
Air leaks at target
leak level (cfm)
-
0.746
kW/hp
x
Annual
Operating
Hours (hrs)
If the facility has a maintenance program that ensures that leaks are monitored, the Annual Energy
Savings is discounted by 50%. Otherwise, it is discounted by 25%.
Measure 2 – Reduce Discharge Pressure
Annual Energy
Savings (kWh)
=
Average normal
operating discharge
pressure (psig)
-
New discharge
pressure (psig)
x
Total Compressor Output
(kWh)
2 psig x 100
Similar to Measure 1, if the facility has a maintenance program that ensures that a reduced setpoint is
maintained, the Annual Energy Savings is discounted by 50%. Otherwise, it is discounted by 25%.
Measure 3 – Use Appropriate Air Dryer
Desiccant Dryer uses 2.5 kW per scfm.
For a cycling or non-cycling dryer, data is used from the CAGI Data Sheets:
Measure 4 – Use Premium Efficiency Motor
The underlying energy savings calculation assumes that the drain uses 85 cfm while open, operates at
100 psig, and costs $0.25 per 1,000 cfm of compressed air. This underlying value is multiplied by the
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number of cycles per hour and then multiplied by the annual operating hours for the compressed air
system.
5.4
VARIABLE SPEED DRIVE (VSD) COMPRESSED AIR ENGINEERED WORKSHEET
5.4.1
Backgrounder - VSD and Fixed Speed Air Compressors
There are two general categories of industrial air compressors:


Positive displacement - includes rotary screw and piston
Dynamic – includes centrifugal
Except for a handful of very large manufacturing facilities which use dynamic compressors, the majority
of industrial facilities employ positive displacement air compressors.
The common way to vary compressor capacity is by controlling inlet or discharge valves. This in turn
restricts the output of the compressor as it continues to run at full speed. Most positive displacement air
compressors become less energy efficient as air demand is reduced. In extreme cases, up to 65% of the
rated electrical power is still used even when there is no demand for air.
For positive displacement compressors, a more energy efficient solution can be achieved by varying the
motor speed. Using this method the power consumption decreases as demand for air reduces.
Many manufacturing facilities can gain financial and energy performance benefits from installing
variable speed (VSD) compressors.
The main advantages of variable speed drives are:



Improved efficiency over fixed speed machines part load conditions under 75%.
Improved discharge pressure control
Eliminating high inrush currents by using soft starting VSD controls thereby extending the
life of the motor
In air systems where multiple compressors are used, the controls can be set so that one or more fixed
speed compressors are operating at full load (usually optimal performance) and the balance of the air is
made by the VSD compressor.
Compressed Air and Gas Institute (CAGI) Data Sheets
The Compressed Air and Gas Institute (CAGI) serves as the unbiased authority on technical, educational,
promotional, and other matters that affect the compressed air industry. CAGI has developed standard
energy performance data sheet formats for:


Fixed speed air compressors
Variable speed drive air compressors
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The CAGI data sheets are only suitable for air compressors with nominal sizes ranging from 25 to 200 hp
and for discharge pressure ratings from 100 to 150 psig. Participating manufacturers can test their air
compressors for energy performance and publish the results using the CAGI format.
It should be noted that the CAGI testing is voluntary in nature. Moreover, the reported results are not
validated by CAGI, but are subject to spot checks. Using the CAGI performance sheets for the VSD Air
Compressor Engineered Worksheet provides an open and transparent method to compare the energy
performance a Fixed Speed and a corresponding VSD compressor.
Participating compressor vendors have published CAGI specification sheets as follows:
Manufacturer
Web Link
http://www.atlascopco.us/usus/aboutus/sales/compressors_generators/cagi.asp
Atlas Copco
http://www.boge.com/us/CAGI/index.jsp?msf=200,100,500
BOGE
http://www.compairusa.com/products_sixty_hz/cagi_data/01fixed_speed_cagi_data_sheets.aspx
CompAir
http://us.fscurtis.com/products/cagi/
FS Curtis
http://www.gardnerdenverproducts.com/compressors/downloads.aspx
Gardner Denver
http://www.ingersollrandproducts.com/cagi_sheets/index.aspx
Ingersoll Rand
http://us.kaeser.com/Advisor/CAGI_data_sheets/default.asp#0
Kaeser
http://www.quincycompressor.com/cagi.html
Quincy
http://www.sullairinfo.com/
Sullair
(Weblinks validated October 2013)
CAGI Fixed Speed Compressor Data Sheet
The standard format for the CAGI fixed speed compressor performance sheet uses the format as shown
in Figure 29.
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Figure 29 - Fixed Speed Air Compressor CAGI Datasheet
5.4.2
Suitability of Use and Limitations
The VSD Compressed Air Engineered Worksheet may not be suitable for some situations. Before
commencing, carefully review the following Validation Statements. If ALL statements are true for the
situation under consideration, then the VSD Compressed Air Engineered Worksheet tool may be used. If
one or more of the Validation statements shown below is not true, then follow the corresponding
suggested step.
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Check








5.4.3
Validation Statement
The intended air compressor
system only has ONE
compressor?


The Fixed Speed and VSD
compressors are positive
displacement machines?
The Fixed Speed and VSD
compressors are 25 to 200
HP in size?
The Fixed Speed and VSD
compressors have maximum
capacity of 2,000 acfm?
The Intended compressor
Operating Discharge
pressure is from 70-150
psig?
There is a CAGI data sheet
available for both the Fixed
Speed, and the VSD
Compressor under
consideration?
The VSD Compressor is
expected to operate less
than 100% of rated capacity
for the vast majority of the
time?

The turndown mode for the
VSD compressor is always
expected to be more 40% of
the rated capacity?

Steps to Take if Validation Statement is NOT True
If there is more than one compressor and NO VSD compressors,
consider using the IESO Compressed Air Engineered Worksheet
If the compressed air system will have more than one compressor,
and will include a VSD compressor, follow the IESO’s “Custom” track
for project evaluation
If the compressor is “Dynamic”, follow the IESO’s “Custom” track
for evaluation

If the compressors are outside the 25-200 HP capacity follow the
IESO’s “Custom” track for project evaluation

If the compressors are outside the 0-2,000 acfm capacity follow the
IESO’s “Custom” track for project evaluation

If the intended operating discharge pressure is outside the 70-150
psig range, follow the IESO’s “Custom” track for project evaluation

If no CAGI sheet is published by the vendor, use the CAGI sheet for
a similar compressor and provide an explanation in the “Notes for
Reviewer” section of the VSD Compressor Worksheet.
If the vendor does not participate in the CAGI specifications follow
the follow the IESO’s “Custom” track for project evaluation
If the VSD Compressor operates at or near 100% of capacity for the
majority of the time, chances are that the more energy efficiency
option would be a Fixed Speed compressor.
The VSD Compressor calculator tool may be used and will provide
an indication of the VSD or Fixed Speed compressor is the more
suitable option
Although VSD compressors have good turndown ratios, in the
majority of cases they should not be operated at less than 40%
rated capacity.
If the system in question, is expected to be operated at less than
40% of rated capacity, even for part of the time, use the “Custom”
track for project evaluation




Typical Operating Pressure
The System Design Assumptions tab requests information on the fixed speed compressor and the VSD
compressor together with information about typical operating patterns, intended operating pressure
and cost factors. Initially, the Engineered Worksheet asks for the Intended Compressor Operating
Discharge Pressure (psig) for the compressed air system as shown in Figure 30.
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Figure 30 - Typical Operating Pressure
5.4.4
Fixed Speed Compressor (CAGI Data Sheet Inputs)
Only some data from the fixed speed compressor data sheet is required for the energy calculations. The
number corresponding to the CAGI data field is shown in the left column. Using the CAGI data sheet,
enter information such as the manufacturer (Note: Use the drop down menu), the model number, rated
capacity, full load operating pressure, and total package input power at zero flow and at rate flow.
Figure 31 shows an example of information entered in the worksheet from the CAGI data sheet.
Figure 31 - Fixed Speed Compressor (CAGI Data Sheet Inputs)
If the Manufacturer is not listed in the dropdown list, select “Other” and then provide a note in the
“Comments & Notes for Technical Reviewer to be Aware of” field.
The worksheet will provide a warning if the flow to power ratio seems to be outside a reasonable
amount (4 to 6 scfm per kW). If it falls outside the range, the user is suggested to double check the
values entered to ensure that they correspond with the CAGI data sheet. The worksheet will also
provide an alert if the full load operating pressure is insufficient to meet the required intended
operating pressure.
Immediately to the right of the data entry section, the worksheet will display a Power Demand (kW)
versus Flow (acfm) performance curve for the fixed speed compressor based on the zero and maximum
flow (known) points. The performance curve is based on a linear equation y = mx + b, where:
y •
=
m
=
b
=
Power Demand (kW)
Maximum Flow Power Demand – Minimum Flow Power Demand
Maximum Flow – Zero Flow
Power Demand (kW) at Zero Flow
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5.4.5
VSD Compressor (CAGI Data Sheet Inputs)
Only some data from the VSD compressor data sheet is required for the energy calculations. The
number corresponding to the data field is shown in the left column. Using the CAGI data sheet, enter
information such as the manufacturer (Note: Use the drop down menu), model number, rated operating
pressure, input power and capacity values and the total power at zero flow capacity as shown in Figure
32.
Figure 32 - VSD Compressor (CAGI Data Sheet Inputs)
If the Manufacturer is not listed in the dropdown list, select “Other” and then provide a note in the
“Comments & Notes for Technical Reviewer to be Aware of” field.
The CAGI VSD Compressor data sheet generally has about 5 pairs of values of input power (kW) and
capacity (acfm) but could have up to eight field pairs. Use Point 1 to show the maximum input power
(kW) and corresponding capacity (acfm). Use Point 2 to show the second highest, Point 3 the third
highest and so on.
IMPORTANT NOTE: If there are no more values to enter (typically at Point 6, 7 or 8), enter the total
package input power at zero flow power values in the next available vacant field (e.g. Point 6 or 7 or 8).
The corresponding flow value will be zero. Enter the total package input power at zero flow again in the
next vacant field (e.g. Point 7 or 8) also showing zero flow, and again in Point 8 if still vacant.
Show the total package input power at zero flow one final time in the field with the namesake field. If
the compressor’s pressure is lower than the intended operating pressure a warning message will show
up.
At the right side of the data entry, a graph of power demand (kW) versus flow (acfm) appears. The
worksheet uses regression to determine the equation of a line that fits the data. The equation is in the
form of y = ax2 + bx + c where:
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y
•
=
Power demand (kW)
x
•
=
Flow (acfm)
=
Coefficients determined by the worksheet
a, b, c
2
The R , or Coefficient of Determination, value is shown in the graph in Figure 29. R2 can have a value
between -1 and +1, and it indicates how well the equation of the curve actually matches the data points.
The closer the R2 value is to 1, the better is the fit.
Tip: A good equation should have an R2 value of more than 0.95. If your R2 value is less than 0.95
recheck the data entry, and if still less than 0.95, use the IESO “Custom” track for the evaluation.
5.4.6
Typical Operating Profile
To complete the estimation of savings, a typical operating profile needs to be inputted. An operating
profile is a representation of the anticipated air flow variation and is usually measured by data-logging
or performing a field test of the compressor system. Flows are allocated into 11 bins which include 10
bins in increments of 10% from 0 to 99.9% and one bin at 100% of flow as shown in Figure 33. The user
is required to provide a short explanation regarding how the compressor profile was determined.
Figure 33 - Typical Operating Profile
The expected flow profile histogram appears immediately to the right of the data entry panel. The
worksheet does not permit entry of flow ranges less than 40% of maximum flow as it is generally a
symptom of over sizing a fixed speed or VSD compressor.
The worksheet will automatically estimate the design basis maximum flow (acfm) shown as a green cell
in the top left portion of the section. If the fixed speed compressor and VSD compressor have different
maximum flow rates, the lesser of the two will be used for an “apples” to “apples” comparison.
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5.4.7
Short Explanation
At the bottom of the Typical Operating Profile section, a box is provided for a short explanation
regarding the method used for estimating the flow profile as shown in Figure 34. It is mandatory to
provide a short explanation since if this field is left blank, the energy savings will default to zero.
Figure 34 - Short Explanation
5.4.8
Comments & Notes for Technical Reviewer to be Aware of
The Comments & Notes for Technical Reviewer to be Aware section is optional. It can be used to note
any important information about the application, including if a substitute CAGI data sheet was used.
If the capacity of the VSD compressor is 10% or more than the capacity of the Fixed Speed compressor,
the following message will display:
Figure 35 - Comments & Notes for Technical Reviewer to be Aware of
5.5
VARIABLE SPEED DRIVE (VSD) ON FANS ENGINEERED WORKSHEET
5.5.1
Fan Overview
Conservative engineering practices often result in the specification, purchase, and installation of fans
that exceed process requirements. Engineers often decide to include a margin of safety in sizing fans to
compensate for uncertainties in the design process, including anticipated future expansions in system
capacity and potential fouling effects.
Variable speed drive (VSD) control for centrifugal fans can, in many situations, offer a more energy
efficient solution when compared to alternative methods, such as throttling, bypassing, and on-off
control.
Fans provide the means to move a gaseous fluid through a system of ductwork. They are widely
classified into two major categories according to the direction of the airflow through the impeller, either
centrifugal or axial.
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
Centrifugal fans  these force the gas to move in a rotational manner with respect to the fan
housing. The centrifugal forces created produce the pressure to move the fluid stream through
the system of ductwork.

Axial fans  these do not create centrifugal forces but impart a velocity that is created as the gas
passes over the blades of an impeller.
A few percentage points of efficiency improvement can save significant energy over the life of the fan.
The five most common ways of controlling a fan include: outlet dampers; inlet dampers; inlet guide
vanes; on – off control; and variable speed drive control.
As a general observation, optimization of a centrifugal fan, with a large horsepower motor and a
continuous operating pattern with variable load, results in the greatest energy savings opportunities for
a VSD application. In many situations, energy savings can be achieved by making changes to the fan’s
hydraulic systems (for example, ducts). Some other measures include: right sizing equipment; trimming
impellers; changing pulley ratios; installing two speed or multispeed motors; and removing system
friction or pressure drop losses. It is assumed that these alternative possibilities have been evaluated
and ruled out before turning to a variable speed drive (VSD) application.
Before completing the VSD on Fans Engineered Worksheet, it is highly recommended that the Applicant
or Applicant Representative be familiar with the following:

Methods to undertake field measurements of power, flow, and pressure for fan systems within
the facility;

Technical principles related to how centrifugal fans function, including the rotational speed and
power consumption relationship for centrifugal drives (affinity laws); and

Fan operational limitations for a specific application including, but not limited to, factors such as:
vibration and noise, resonance, pipe/duct fatigue, pipe erosion, mechanical limitations, and zones
of instability.
5.5.2
Fan Curve and Operating Profile
A key purpose of fan data gathering is to determine the system performance curve and to establish, or
verify, specific operating points for the load duty curve. To ensure reliable analysis, information about
flow, speed, pressure, temperature, brake horsepower, and other parameters should be obtained.
In reality, there are situations where not all this information is readily available. However, with a
reasonable understanding of system operation, and by using existing records and information from
operators together with good judgment, it is possible to approximate the operating points and to
establish a relatively accurate fan load condition.
The system resistance curve can be estimated when system effect factors are taken into account. These
factors include individual system resistances brought about by the physical configuration or layout of
the equipment and associated pipes or ducts.
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As with any measurements, the accuracy of energy efficiency analysis depends on the source, accuracy,
and reliability of the data inputs. Common sources for information include: design data from fan curves,
observations and estimates from plant operations personnel, equipment nameplate data, operating
records, temporary metering, and temperature of the gas being moved.
Determining what data is the most valuable can be a matter of experience and applying sound technical
judgment. One also needs to consider whether a fan’s fluctuating output could be brought about by
changes in batch operation, alterations or variations in material being processed, and seasonality or
weather impacts.
The System Design Assumptions tab collects information on the base case and the efficient case for a
series of potential improvements to the fan system.
Note: Fans and fan systems are comprised of different components and configurations and the energy
efficiency results for multiple measures may not be additive.
As noted, before completing the worksheet, it is important to gather all the necessary information and
have it readily available. The following information is needed:

Fan Design Flow (CFM) – this is the design (100%) flow, in cubic feet per minute, that the fan
has been designed for.

% Flow  this indicates the percentage of full flow in which the system is being operated. (That
is, 0-10% indicates operation between 0% of full flow and 10% of full flow. This range is called a
flow bin.).

Design Head (Inch Water Gauge) – is the corresponding pressure lift developed by the fan at a
given flow rate in inches water column; it is usually determined from the as-built Fan Curve
provided by the fan supplier.

Corresponding Fan Efficiency (%) – this is the fan efficiency indicated on the Fan Curve for a
particular flow and head; if efficiencies are shown as families of curves, and an operating point
falls between two curves, the average may be used.

Operating Profile (%)  the user should enter the percentage of time during which the system
operates in the specified flow regimes; this information is obtained from field measurements at
the site (for example, a fan can range in operation from 40% to 100%, with the most common
operating point occurring in the 80% – 90% flow bin); operating points should be adjusted such
that the sum of the numbers shown in the Operating Profile % is equal to 100%. The worksheet
will display “YES” when the 100% criterion is met.
The Fan Curve box on the right hand side of the worksheet will automatically display a curve when the
Fan Design Flow and the Design Head for each percent Flow are filled-in.
Notes:
1) The user should enter the flow and efficiency values for the midpoint of the bin range. For example,
for the 90%-100% bin, one would enter the design head corresponding to 95% flow.
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2) The Fan Curve also produces a polynomial curve fit along with an R2 value for a regression model.
When entering data from a hard-to-read Fan Curve, minor adjustments (upwards or downwards)
can be done to the design head to get the R2 value to be as close as possible to 1.0.
See Figure 36 for an example of a Fan Curve that resulted from the information input on the left.
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Figure 36 – Fan Curve and Operating Profile
Important note:
5.5.3
Some fans will not function properly in certain flow and pressure zones. For example,
operating at a certain point may result in mechanical resonance or instability. It is
critical to use good engineering judgment in conjunction with the manufacturer’s
performance curve, conditional assessment, and actual field measurements before
deciding on recommendations and retrofit designs.
Fan and Motor Information
In the Fan and Motor Information section of the System Design Assumptions tab,information about the
motor speed and horsepower, gas temperature and density, design head and static head, and make and
manufacturer of the fan and motor, with the corresponding estimated age, is collected. This information
is described below:

Motor Rated Speed (rpm)  this is the manufacturer’s rated speed (full-load), which can be found
on a motor’s nameplate.

Motor Rated Power (hp) – this is the nameplate rating for the motor.

Gas Temperature (F)  this is the temperature of the gas flowing through the fan. As hotter gases
are less dense, the worksheet makes adjustments for fan performance based on gas temperature.
The default value is 68F.

Density of Gas (lbs/ft3)  by definition, air is assigned a density of 0.075.If the gas being
transported is not air, revise the density value accordingly.

Design Head (Inch Water Gauge)  from the Fan Curve, enter the Design Head corresponding to
the system design flow point.
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
Static Head (Inch Water Gauge)  this is the pressure differential caused by height differences, or
pressure differences, between vessels. In addition to overcoming friction, the fan must also
overcome static head in order to transfer fluid from one point to another. It is important to
include this information because the fan affinity laws (power requirement is proportional to the
cube of the speed) may need to be adjusted for the presence of static head. Note, however, that
the vast majority of fan applications do not have a significant static head component.

Fan Make and Model  enter this information for the motor and the fan, along with the
Approximate Ages (years).
The Fan Operating Profile box on the right of the Fan and Motor Information table will automatically
display the Operating Profile (graph) when the Fan and Motor Information is entered. Figure 37 shows
an example of this.
Figure 37 – Fan and Motor Information
5.5.4
Fan and Motor Efficiency
Information on fan and motor efficiencies is needed to estimate the Energy Savings (see Figure 38).
Motor efficiency at full load can be obtained from the motor manufacturer, or estimated from generic
values published by NRCan or the US Department of Energy, or by looking up the value in the freely
available CanMOST database.6 The Fan Efficiency at Damper Fully Open value is obtained from the Fan
Curve at the Fan Design Flow point.
6
Available for download free of charge from the Department of Natural Resources Canada – Office of Energy
Efficiency http://oee.nrcan.gc.ca/industrial/equipment/software/intro.cfm
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Figure 38 – Fan and Motor Efficiency Information
The following other motor efficiency correction factors, expressed as decimal fractions, also should be
input:

Motor Efficiency Correction Factor for Lower Loads – this accounts for part loading of the motor,
typically ranging from 80- 95%. Default value is 0.96.

VSD Efficiency Factor (When Operating > 40% Load) – this accounts for part loading of the
variable speed drive, typically ranging from 90-98%. This factor can be obtained from the VSD
supplier. Default value is 0.95

Motor Efficiency Correction Factor for VSD Operation – this accounts for the interactive effects
between the motor and the variable speed drive when part loading with values typically ranging
from 80- 95%. Default value is 0.82.

Belt/Coupling Efficiency Factor – this accounts for the transmission efficiency between the motor
and fan. Default value is 0.96.
Note: Sometimes these factors are difficult to obtain. If the information is not available, pick a
reasonable value from the ranges indicated above. Note that the worksheet will only use the
efficiency correction factors when the flow is more than 60% of design. Various diminishing
factors are applied in place of the values entered by the user when the flows are less than 60%.
When the Fan and Motor Efficiency information is entered, a graph representing the Conventional &
VSD Energy by Operating Point will automatically display. Figure 35 shows an example of this graph. The
green bars indicate the expected energy consumption with the conventional system (that is, throttle)
and the blue bars indicate the energy using a VSD.
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5.6
VARIABLE SPEED DRIVE (VSD) ON PUMPS ENGINEERED WORKSHEET
5.6.1
Pump Overview
Similar to fan applications, variable speed drive (VSD) control for centrifugal pumps can, in many
situations, offer a more energy efficient solution when compared to alternative methods, such as
throttling, bypassing, and on-off control.
A centrifugal pump is a rotodynamic pump that uses a rotating impeller to create flow by the addition of
energy to a fluid. Centrifugal pumps are commonly used to move liquids through piping. The fluid enters
the pump impeller along, or near, the rotating axis and is accelerated by the impeller, flowing radially
outward into a diffuser or volute chamber (casing), from where it exits into the downstream piping.
Centrifugal pumps are generally divided into three general categories:
1) Radial Flow Pumps  the fluid enters the pump impeller along its axis, is accelerated by the
impeller and exits outward perpendicular to the shaft (radially).
2) Axial Flow Pumps  the fluid enters in a direction that is parallel to the rotating shaft and
discharged with minimal friction and no change in direction.
3) Mixed Flow Pumps  these pumps are a combination of radial and axial flow pumps; the fluid is
accelerated with a push from the axial direction of the impeller and discharged diagonally
somewhere between 0–90 degrees from the axial direction.
Before completing the VSD on Pumps Engineered Worksheet, it is highly recommended that the
Applicant or Applicant Representative be familiar with the following:

Methods to undertake field measurements of power, flow, and pressure for pump systems within
the facility;

Technical principles related to how centrifugal pumps work, including the rotational speed and
power consumption relationship for centrifugal drives; and

Pump operational limitations for a specific application including, but not limited to, factors such
as: vibration and noise, resonance, pipe/duct fatigue, pipe erosion, mechanical limitations, and
zones of instability.
5.6.2
Pump Curve and Operating Profile
The System Design Assumptions tab collects information on the base case and the efficient case for a
series of potential improvements to the pump system.
Note: It is important to recognize that pumps are comprised of different components and
configurations and the energy efficiency results for multiple measures may not be additive.
As noted, before completing the worksheet, it is important to gather all the necessary information and
have it readily available. The following information is needed:
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
Pump Design Flow (GPM) – this is the design (100%) flow in U.S. gallons per minute that the pump
has been designed for.

% Flowthis indicates the percentage of full flow in which the system is being operated. (That is,
0-10% indicates operation between 0% of full flow and 10% of full flow. This range is called a flow
bin.)

Pump Head (ft) – this is the corresponding height of liquid column developed by the pump at a
given flow rate; it is usually read from the Pump Curve.

Corresponding Pump Efficiency (%) – this is the pump efficiency indicated by the Pump Curve for
a particular flow and head; if efficiencies are shown as families of curves and an operating point
falls between two curves, the average may be used.

Operating Profile (%)  the user must enter the percentage of time during which the system
operates in the specified flow regimes; this is obtained from field measurements at the site (for
example, a pump can range in operation from 40% to 100%, with the most common operating
point occurring in the 80% – 90% flow bin); operating points should be adjusted such that the sum
of the numbers shown in the Operating Profile % is equal to 100%.The worksheet will display
“YES” when the 100% criterion is met.
The Pump Curve box shown on the right hand side of the worksheet will automatically display a curve
when the Pump Design Flow and the Pump Head for each percent Flow are filled-in. Figure 39 shows the
Pump Curve corresponding to the information filled in on the left.
Notes:
1) The user should enter the flow and efficiency values for the midpoint of the bin range. For example,
for the 90%-100% bin, one would enter the design head corresponding to 95% flow.
2) The Pump Curve also produces a polynomial curve fit along with an R2 value for a regression
model. When entering data from a hard-to-read Pump Curve, minor adjustments (upwards or
downwards) can be done to the design head to get the R2 value to be as close as possible to 1.0.
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Figure 39 – Pump Curve and Operating Profile
Important note:
5.6.3
Some pumps will not function properly in certain flow and pressure zones. For
example, operating at a certain point may result in mechanical resonance or
instability. Before deciding on recommendations and retrofit designs it is critical to
use good engineering judgment and to take into account the manufacturer’s
performance curve, conditional assessment, and actual field measurements before
deciding on recommendations and retrofit designs.
Pump and Motor Information
In this section of the System Design Assumptions tab, information about the motor speed and
horsepower is entered. In addition, enter the fluid temperature and specific gravity. For pumps, the
default specific gravity for water is 1.00. Enter the pump head or design head that would correspond to
the Pump Design Flow previously entered. The static head for a pump should also be entered. It is
important to include this information because the pump affinity laws (power draw is proportional to the
cube of the speed) may need to be adjusted for the presence of static head. The information that should
be entered is:

Motor Rated Speed (rpm)  this is the manufacturer’s rated speed (full-load), which can be found
on the motor’s nameplate.

Motor Rated Power (hp) – this is the nameplate rating for the motor.

Fluid Temperature (F)  this is the temperature of the fluid that is being pumped. As hotter
liquids are less dense, based on fluid temperature, the worksheet makes adjustments for pump
performance.

Specific Gravity  by definition, water is assigned a specific gravity of 1. If the liquid being pumped
is not water, revise the specific gravity value accordingly.
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
Design Head (Inch Water Gauge)  using the Pump Curve, enter the Pump Head (ft)
corresponding to the Pump Design Flow point. Note that the Design Head corresponds to the
point on the Pump Curve for the design flow (that is, the flow point shown in the input cell for
“Pump Design Flow in US Gallons per Minute”).

Static Head (Inch Water Gauge)  this is the pressure differential caused by height differences, or
pressure differences between vessels, and is unique to the specific layout of each individual
facility. Static Head cannot be read from a Pump Curve, however, an indication of Static Head
considerations may be available from the original system design documentation. In addition to
overcoming friction, the pump must also overcome Static Head in order to transfer fluid from one
point to another.

Pump Make and Model numbers  enter this information for the motor and the fan along with
the Approximate Ages (years).
The Flow Duration Profile box to the right of the Pump and Motor Information table will automatically
display the Fan Duration Profile (graph) when the Pump and Motor Information is entered. Figure 40
shows an example of this.
Figure 40 – Pump and Motor Information
5.6.4
Pump and Motor Efficiency
Information on pump and motor efficiencies is needed to estimate the Energy Savings (see Figure 41).
Motor efficiency at full load can be obtained from the motor manufacturer, or estimated from generic
values published by NRCan or the US Department of Energy, or by looking up the value in the freely
available CanMOST database7. Next, the pump efficiency value (obtained from the Pump Curve) at the
Pump Design Flow point is entered.
7
Available for download free of charge from the Department of Natural Resources Canada – Office of Energy
Efficiency http://oee.nrcan.gc.ca/industrial/equipment/software/intro.cfm
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Figure 41 – Pump and Motor Efficiency Information
The following other motor efficiency correction factors, expressed as decimal fractions, are also input:

Motor Efficiency Correction Factor for Lower Loads – this accounts for part loading of the motor,
typically ranging from 80% 95%. Default value is 0.96.

VSD Efficiency Factor (When Operating > 40% Load) – this accounts for part loading of the
variable speed drive, typically ranging from 90%98%. This factor can be obtained from the VSD
manufacturer. Default value is 0.95

Motor Efficiency Correction Factor for VSD Operation – this accounts for the interactive effects
between the motor and the variable speed drive when part loading, with values typically ranging
from 80% 95%. Default value is 0.82.
Note: Sometimes these factors are difficult to obtain. If this information is not available, pick a
reasonable value from the ranges indicated above. Note that the worksheet will use the
efficiency correction factors when the flow is more than 60% of design. Various diminishing
factors are applied in place of the values entered by the user when the flows are less than 60%.
In the box to the right of the Pump and Motor Efficiency information, the Conventional & VSD Energy
by Operating Point graph will automatically display when the Pump and Motor Efficiency information is
entered. The blue bars indicate the expected energy consumption with the conventional system (that is,
throttle) and the red bars indicate the energy using a VSD.
5.7
UNITARY AIR CONDITIONING (A/C) ENGINEERED WORKSHEET
The energy performance of unitary roof-top and ductless split A/C systems is largely defined by their
energy efficiency ratio (EER). How much energy is saved over the course of a year for a high efficiency
unitary system is determined by the annual cooling delivered by the system and the EER rating. This
Engineered Worksheet calculates the savings associated with retrofitting an existing inefficient unitary
A/C with an energy efficient unit, as well as the impacts of a change in unit capacity.
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5.7.1
Applicant and Space Information
In the Applicant and Space Information section, information about the unitary A/C project description,
worksheet description, worksheet number, total number of worksheets, account number and facility
description is entered. Figure 42 shows a sample of this section filled in for a hypothetical Restaurant.
Lastly, a reference facility should be selected from the dropdown list.
Figure 42 – Reference Facility
There are 8 reference facilities listed in the dropdown list: Office, Big Box Retail, Strip Mall Retail, Ice Pad
Arenas (excluding Pad cooling), Community Centre, Food Retail, Hotel and Restaurant. These reference
facilities were developed using a database of whole building energy models developed over 15 years.
These models were created using EE4 software, a software developed by NRCan as a compliance
checking tool for the Model National Energy Code for Buildings (MNECB) and NRCan’s own validation.
Table 2 shows the assumed characteristics for the various reference facilities.
Table 2 – Archetype Data for the Reference Facilities
REFERENCE
FACILITY
Big Box Retail
Strip Mall Retail
Office
Community
Centre
Ice Pad Arenas
Store with 1-6 Roof Top Units
10,485
YEAR
COMPLETED
2008
Store with 1-15 Roof Top Units
13,166
2008
Stripmall 1 with 11 units (pet store,
restaurants – subs, pizza, pita, hair
salon)
3,500
2008
Stripmall 2 with 8 units
2,500
2008
4,500
2008
AREA (m2)
DESCRIPTION
Stripmall 3 with 6 units in Bldg. A and
7 units in Bldg. B (grocery, pharmacy,
clinic, dentist, salon, coffee shop)
1-2 units each serving one floor of
office
Systems 2,3,8,9 are Roof Top Units.
Other zones are Variable Air Volume
5 units (units serving ice pad areas are
not included)
2,000 (2 floors of office
space)
2,500 served by RTUs out
of 7,300 m2 total building
10,250 (building area)
2005
2008
2008
In 2014, three reference facilities, namely, food retail, hotel and restaurant, were added to the
engineered worksheet. The following describes the assumptions used in generating the energy models
for these reference facilities:
Food Retail
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Two food retail models were used to generate the cooling load profiles for this building type. Focus was
placed on only the systems which serve the sales areas of the buildings. The models that were used to
generate these curves did not initially have open refrigerated/freezer casework loads included. These
aspects were incorporated into the model based on average loads found in grocery stores based on
information obtained from the National Renewable Energy Laboratory Council8. The table below
summarizes the loads added to each model.
Table 3- Loads Added to the Food Retail Models.
Case Type
Island Single Ice Cream
Island Single Deck Meat
Multi-Deck Dairy/Deli
Capacity
Btu/h/ft
740
770
1500
Length/Area
ft/1000 ft2
0.972
4.508
7.859
Sensible
Heat
0.853
0.639
0.759
Temp (F)
-13.0
28.5
41.0
Auxiliary
(kW)
3.0
1.9
22.0
Grocery Store 1 is assumed to have a total area of 2,333 m² (25,112 ft²) with the following assumed
spaces: 81% Sales (served by a single roof top unit); 2% Produce/Preparation (served by a unit heater);
13% Receiving (served by a unit heater); and 4% Office (served by a single roof top unit).
Grocery Store 2 is assumed to have a total area of 4,527 m² (48,729 ft²) with the following breakdown of
spaces: 72% Sales (served by 5 single roof top units); 26% Stock/Preparation (served by a unit heater);
and 2% Office (served by a single roof top unit).
Hotel
The amenity and public spaces in the hotel were the focus of this building type. The analysis of this
building type was done by extracting the amenity spaces in the building and assigning single-zone
unitary systems to each of the applicable zones. The total area of the amenity/common spaces is
assumed to be 6,164 m² (66,330 ft²) equipped with 20 unitary systems. The space is assumed to consist
of 21% Meeting Rooms; 32% Ballroom; 27% Lobby; 7% Amenity; 3% Fitness; 2% Storage; and 8% Office.
Restaurant
The Restaurant/Dining building type assumed that the make-up air for the kitchen and washroom
exhaust is served by air supplied to the dining spaces. The total area of the space is assumed to be 537
m² (5,780 ft²) equipped with one unitary system and consists of 70% Dining, 20% Kitchen and 10%
Washroom.
5.7.2
Load Duration Curve
Once the reference facility has been selected, the Engineered Worksheet produces a default Load
Duration Curve based on the chosen reference facility. The Load Duration Curve indicates the
percentage of time the unit operates at each partial load. This load duration information is also
presented in format on the right hand side of the table.
8
Leach, M., Hale, E., Hirsch, A., & Torcellini, P. (2009, September). Grocery Store 50% Energy Savings Technical
Support Document . Technical Repor tNREL/TP-550-46101. Golden, Colorado, United States of America: National
Renewable Energy Laboratory.
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Note: The Load Duration Curve method is only accurate when the system operation schedule entered
corresponds to the times when cooling is typically needed within the building (generally 9am 5pm from June to September for the archetype load duration curves). Significant deviation from
this period may result in significant overestimation of energy consumption.
5.7.3
System Operating Schedule – Cooling Season Only
Since the Unitary A/C Engineered Worksheet is for air conditioning, the system operating schedule that
is entered is for the cooling season only. Up to three (3) periods during the cooling season can be
entered. To ensure that the number of operating hours is properly entered, when entering dates and
time it is important to always use the drop down menus. An example is shown in Figure 43.
Figure 43 – System Operating Schedule – Cooling Season Only
Using a schedule that includes many hours when the A/C unit would be off introduces significant error
into the calculation method. The unitary A/C Engineered Worksheet assumes that the unitary A/C
operates during the cooling season only. If there is only one operating schedule for the cooling season,
enter the schedule only under Season 1. If there is more than one operating schedule for the cooling
season (e.g. different On Time and Off Time for the cooling months) as in the case of some schools,
enter the schedule under Season 2 and Season 3.
5.7.4
Floor Area and Climate
The floor area served by the A/C unit in square meters is entered next, as shown in Figure 44. The
amount of cooling per square area is compared with the ASHRAE cooling check loads.
Figure 44 – Floor Area and Climate
Another important input for the Unitary A/C Engineered Worksheet is the selection of the climate
region. This selection determines which set of weather data is used within the calculations. The weather
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data comes from the files used by the software EE4 by NRCan and contains an hourly wet and dry bulb
temperature that is used in the analysis. There are 4 climate regions to choose from in the dropdown
list: Southern Ontario - West (e.g. Windsor), Southern Ontario (e.g. Toronto), Eastern Ontario (e.g.
Ottawa), and Northern Ontario (e.g. Sault Ste Marie).
5.7.5
Existing AC Unit and Replacement Unit Cost
In addition to providing the manufacturer, series, and model of the existing and replacement A/C units,
the user is asked to provide the unit capacity (Btu/hr) and the Energy Efficiency Ratio (EER) for both the
existing and retrofit (replacement) A/C units. The user can add up to 3 A/C unitary systems which are
differentiated by capacity and EER. Drop down menus allow the user to select the quantity of each
system (up to 20 each). The quantity of the existing system is assumed to equal the quantity of the
replacement system. Figure 45 shows an example of this information filled in.
Figure 45 – Existing and Replacement Units
5.8
PROJECT COST BREAKDOWN INFORMATION
All Engineered Worksheets require the user to enter data on economic values and project costs under
the System Design Assumptions tab. Inputting the Project Cost Breakdown information allows for
calculation of Total Eligible Costs for the Project.
5.8.1
Economic Values
The last section under the System Design Assumptions tab requires information on Economic Values and
Project Cost Breakdown. This information is needed to describe the economics of the project as
indicated under the Outputs tab. Economic Values inputs include the Blended Cost of Power ($/kWh)
and an Estimated Monthly Demand ($/kW). These values may be obtained from utility bills. Figure 46
provides an example of the Economic Values and Project Cost Breakdown sections filled in.
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Figure 46 – Economic Values and Project Cost Breakdown
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5.8.2
Project Cost Breakdown
The Project Cost Breakdown relates to the following information related to the procurement and
implementation of the eligible equipment or measure:

Actual total costs of the equipment purchased (not including spare parts)

Actual total costs charged by suppliers of labour for the installation of the equipment

Total costs to dispose of or decommission the replaced equipment

Total costs of inspections of the Project as may be required pursuant to Laws and Regulations
Note: the Project Cost Breakdown information for the Commercial Lighting Engineered Worksheets
does not make use of the Zone Multiplier but, instead, should reflect the actual eligible project
costs of all the retrofit lighting fixtures included in the Worksheet. For example, a retrofit lighting
project required the submission of two Commercial Interior Lighting Worksheets for a single
zone. The first worksheet contained a total of 120 retrofit lighting fixtures while the second
worksheet contained a total of 60 retrofit lighting fixtures. The Project Cost Breakdown that
must be reflected in the first worksheet must correspond to the total costs of the 120 fixtures.
Likewise, the Project Cost Breakdown for the second worksheet must correspond to the total
costs of the 60 fixtures.
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6)
OUTPUTS TAB
The Outputs tabs on the Engineered Worksheets present the Project Engineering Estimates, the Project
Economics, and the LDC Quality Control (QC) and Diagnostics for the retrofit project.
6.1
PROJECT ENGINEERING ESTIMATES
The Project Engineering Estimates box highlights the Maximum and Average Summer and Winter Peak
Demand in kW and the Annual Electricity Consumption in kWh for both the base and retrofit case. It also
presents the Average to Maximum Ratio peak demand for both summer and winter. The RETROFIT
PROGRAM recognizes the summer peak as the basis for its Demand Savings. Figure 47 shows an
example of this information.
Figure 47 – Project Engineering Estimates
The Maximum Summer Peak Period Demand (kW) is the Total Connected Load for the base and retrofit
system occurring during the summer on-peak period (June 1 – Sept. 30) between 11 am and 5 pm on
business days. Likewise, the Maximum Winter Peak Period Demand (kW) is the Total Connected Load for
the base and retrofit system occurring during the winter on-peak period (Dec. 1 – March 31) between 7
am and 11 am and 5 pm and 8 pm on business days.
The Average Summer Peak Demand (kW) is the amount of electricity consumed in kWh divided by the
available number of hours (assumed to be 510 hours) during the summer on-peak period. Likewise, the
Average Winter Peak Demand (kW) is the amount of electricity consumed in kWh divided by the
available number of hours (assumed to be 588 hours) during the winter on-peak period.
The Average to Maximum Ratio is calculated by dividing the Average Peak Demand by the Maximum
Peak Period Demand. This ratio provides information on the degree of coincidence of the average peak
demand to the total connected load or maximum peak demand of both the base and retrofit system
given the system schedule.
The Annual Energy Consumption (kWh) is the amount of electricity consumed for the year based on the
equipment schedule, including adjustments for statutory, civic or other holidays, as entered in the
System Schedule tab.
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In the following sections, the algorithm or methodology for calculating the maximum summer peak and
winter peak period demand (kW) and energy (kWh) savings is discussed for the various types of
measures.
6.1.1
Combined Commercial Lighting
The Maximum Summer Peak and Winter Peak Period Demand Savings for all three Commercial
Engineered Lighting Worksheets are calculated using the following equation:
Maximum Peak Period
Demand Savings (kW)
=
Total Connected Lighting
Load per Zone (Base)
-
Total Connected Lighting
Load per Zone (Retrofit)
In normal cases, the Maximum Summer Peak and Winter Peak Period Demand savings will be equal.
There will be situations when either the Maximum Summer Peak or Maximum Winter Peak Period
Demand Savings will be zero. This happens when there is no operation during the hours within the
summer or winter peak period.
The Annual Energy Consumption (kWh) is the sum of all electricity consumed for the year based on the
operating schedule, including adjustments for statutory, civic or other holidays as entered in the System
Schedule tab.
6.1.2
Lighting Controls
The calculation for the lighting control savings are performed on an hourly basis. This enables the
worksheet to accurately account for the user’s schedule as entered. As the percentage of savings that
each control type should result in is known, these fractions are applied to the fixture power in each hour
as a multiplier.
Occupancy/Vacancy Sensor Savings
The savings that result from the implementation of occupancy/vacancy sensors is dependent on the
space type and on the specific patterns of use. As occupancy sensors turn the lighting on when
occupants enter the space, the savings are dependent on the amount of time that occupants spend in
the space. Human behavior is also a factor. If the space occupants are already diligent about turning
the lights off as they leave, installation of occupancy sensors will result in very low savings. As both the
percentage of time spent in the space and user behavior are extremely difficult to quantify, calculations
of the savings of installing sensors in a specific space is not realistic. The best way to provide accurate
estimates of savings from occupancy sensors is to use established values determined through research.
This enables accurate results with simple user inputs.
A review of existing studies was conducted to determine the rate of savings of occupancy sensors within
different spaces. These results were reviewed, tabulated and averaged to select the values savings rates
used in the worksheet. The values used in the calculations are summarized in the table below.
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Figure 48 - Percentage Savings of Occupancy Sensors for Different Space Type
Space Type
Private Office
Open Office
Classroom
Conference/Meeting Room
Warehouse
Cafeteria
Gymnasium
Changeroom/Restroom
Storage Room
% Savings
35%
25%
30%
40%
60%
30%
30%
50%
55%
Vacancy sensors operate similarly to occupancy sensors with the difference that the user must always
turn on the light. Vacancy sensors save additional energy as they influence user behavior towards
having the lights off. It is assumed that vacancy sensor savings is two percent greater than the
associated occupancy sensor. This value was selected based on engineering judgement and can be
adjusted if more accurate information becomes available.
Daylight Sensor Savings
The performance of daylight sensors is defined by the amount of outdoor light entering a space and the
level of control that the sensor has over the lighting. Daylight sensors are of three general types: on/off,
stepped dimming, and fully modulating dimming. The amount of light entering the space is a function of
the size of the windows within a space, the orientation of the windows, the visible light transmittance of
windows, and the time of day. These variables were explored through parametric simulations to
determine the impact on the savings generated by the installation of daylight sensors.
The parametric study was performed using eQuest modelling software developed by the State of
California to provide a freeware building simulation tool for energy efficiency analysis. This software is
capable of calculating and comparing between different types of daylight sensor and utilizes a diffuse
lighting calculation to determine daylighting levels and the resulting electric lighting control responses.
The parametric modeling runs were designed to evaluate the impact of each building input
independently. Building orientation was not evaluated as this is a difficult parameter for the user to
enter as buildings have windows on multiple faces and at non-cardinal directions. Modeling runs were
performed on a square space with equal window area on all building faces. Initial investigative runs
provided the ranges of the variables to be evaluated. All three types of daylight controls were
evaluated. Time of day was evaluated for each of the time of use bins (excluding off-peak hours as
these occur at night). This seemed appropriate as this corresponds to the output of the tool. Window
visible transmittance was evaluated at 0.4, 0.6 and 0.8 to provide for a range of glazing types. Window
to wall ratios of 20, 40 and 60 were explored, as preliminary results showed little additional benefit from
60 to 100.
Following the parametric runs, the data was analysed. As both the window to wall ratio and the window
visible transmittance impact the amount of light entering the space, these variables were multiplied for
ease of analysis. Trend lines were then fitted to plots of the data relating to Tvis x Window to Wall ratio
to percentage savings. See Figure 49 below for an example of three (3) trend lines corresponding to the
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three (3) types of daylight sensors for the shoulder season mid peak period. There were 15 empirical
equations (3 control types x 5 time of use periods) that were derived from the eQuest parametric runs
to calculate the savings at any time of the year. Table 4 shows the coefficients of the trend lines.
Figure 49 - Saving curve for the shoulder season mid-peak period
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Figure 50 - Saving curve for the summer season mid-peak period
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Figure 51 - Saving curve for the summer season peak period
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Figure 52 - Saving curve for the winter season peak period
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Figure 53 - Saving curve for the winter season mid-peak period
Table 4 - Coefficients for Developed Trend Lines
Weather Bin
Daylight Sensor
Type
x
6
x
x
x
x
x
0
0
-2.2E-07
3.55E-05
-0.00212
0.058727
1.72E-10
-8.4E-09
-1.4E-06
0.000147
-0.00541
0.0931
-6E-10
1.24E-07
-1E-05
0.000439
-0.01011
0.124218
On/off
9.26E-10
-1.6E-07
9.87E-06
-0.00029
0.003431
0.006636
Stepped dimming
4.47E-10
-6.5E-08
3.3E-06
-5.2E-05
-0.00087
0.040425
Fully
modulating
dimming
1.6E-12
1.41E-08
-2.2E-06
0.000137
-0.00411
0.064292
0
1.03E-08
-1.8E-06
0.00012
-0.00409
0.074684
Stepped dimming
-4.64E-10
9.93E-08
-8.4E-06
0.000366
-0.00867
0.110821
Fully
modulating
dimming
-9.9E-10
1.93E-07
-1.5E-05
0.00059
-0.01242
0.136622
On/off
Winter Mid
Peak
Winter Peak
Stepped dimming
Fully
modulating
dimming
On/off
Shoulder
Mid Peak
5
4
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2
1
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Weather Bin
Summer
Mid Peak
Summer
Peak
6.1.3
Daylight Sensor
Type
6
5
4
3
2
1
x
x
x
x
x
x
On/off
1.13E-10
-8.5E-09
-5E-07
7.75E-05
-0.00345
0.072519
Stepped dimming
-5.58E-10
1.14E-07
-9.4E-06
0.000396
-0.00917
0.115305
Fully
modulating
dimming
-1.03E-09
1.98E-07
-1.5E-05
0.00059
-0.01242
0.137772
On/off
-1.09E-09
2.2E-07
-1.8E-05
0.000746
-0.01692
0.200126
Stepped dimming
-2.65E-09
4.85E-07
-3.5E-05
0.001295
-0.02529
0.249974
Fully
modulating
dimming
-3.19E-09
5.77E-07
-4.1E-05
0.00149
-0.0283
0.268002
Compressed Air
The calculation of the Annual Energy Savings and Annual Demand Savings for implemented measures
under the Compressed Air Engineered Worksheet is discussed in Section 5.3.8.
6.1.4
Variable Speed Drive Compressed Air
Power demand for the fixed speed and VSD compressed air are estimated based on the generated linear
and polynomial equation, respectively. This calculation is done for each of the 11 bins representing
different percentage flows.
For each of the 11 bin, power demand for the fixed speed compressor is assumed to follow a straightline relationship with the flow and is represented by the equation y = mx + b where:
y
x
=
=
m
=
b
=
Power demand (kW) for a given flow
Given flow (acfm)
Total Package Input @ Rated Capacity and Full Load Operating
Pressure – Total Package Input Power @ Zero Flow
Rated Capacity @ Full Load Operating Pressure
Total Package Input Power @ Zero Flow
The total power demand for the fixed speed compressor is then averaged according to the given
operating profile.
Likewise, for the VSD compressor, power demand is assumed to have a polynomial relationship with the
flow and represented by y = ax2 + bx + c as discussed in Section 5.4.5. Power demand is calculated for
each of the 11 bin and the total power demand is then averaged according to the given operating
profile.
Power demand for both fixed speed and VSD compressor is adjusted depending on the intended
compressor operating pressure. This power adjustment correction factor is used to normalize the
expected power to the intended operating discharge pressure conditions so that an equitable
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comparison can be made between the fixed speed and VSD compressor options. It is assumed that the
power requirements for both the fixed speed and VSD compressor are reduced by 0.5% for each 1 psig
reduction in discharge pressure.
Demand (kW) savings is calculated as follows:
Demand Savings (kW)
Power Demand of Fixed
Speed Compressor
=
-
Power Demand of VSD
Compressor
Energy savings takes into account the lesser of the Fixed Speed Compressor Rated Capacity at Full Load
Operating Pressure value (acfm) and the VSD Compressor Rated Capacity at Full Load (acfm). It is
calculated by multiplying the demand savings (kW) by the Annual Operating Hours.
Energy Savings (kWh)
6.1.5
=
Demand Savings (kW)
x
Annual Operating Hours (H)
Variable Speed Drive on Fans
Savings calculations for Variable Speed Drive on Fans start with the calculation of the Annual Energy
Savings (kWh), which is the difference between the annual energy consumption (kWh) of the
conventional fan system (base) and the fan system with the VSD (retrofit). This calculation is done for
each of the 10 bins representing 10 different percentage flows.
For each bin in the conventional fan system, the fan horsepower (FHP) is calculated using the following
equation:
FHPb
where: FHPb
Qb
=
=
=
Qb x P x 
fan x 6356
P
=

=
fan
=
Fan horsepower (hp)
Average air flow rate for bin range in cubic foot per
minute (CFM)
Design head for the bin range in inches of water
(“WG)
Density ratio of the gas to air in lbs/ft3; air is assumed
to have a density of 0.075 lbs/ft3
Fan efficiency at flow rate (decimal)
6356
=
Conversion constant
The conventional fan system energy consumption (kWh) for each bin is calculated using the following
equation:
kWhb =
FHPbx 0.746 x H
motor x belt/coupling
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 70 of 75
where: kWhb
FHPb
H
=
=
=
belt/coupling =
Energy consumption in the bin range
Fan horsepower (hp) calculated for the bin range
Number of operating hours in the bin range; this is
calculated by getting the percentage hours for the bin
range as dictated by the Operating Profile
Motor full load efficiency (decimal) x Motor efficiency
correction factor (decimal)
Belt/Coupling efficiency factor (decimal)
motor
=
0.746
Conversion constant from horsepower to kilowatt
=
The total annual energy consumption for the base case is the sum of all the energy consumption in the
10 bins.
For Variable Speed Drive on Fans, the annual energy consumption in kWh is calculated the same way as
for the Conventional Fan System except that there is an additional definition for total head and
efficiencies.
= Ps + (Pd – Ps) ( Q / Qd ) 2
P
where: P
=
Ps
=
Pd
Q
=
=
Qd
=
System head for the bin range in inches of water
(“WG)
Static head for the fan system in inches of water
(“WG);
Design head (at X) in inches of water (“WG)
Average air flow rate for bin range in cubic foot per
minute (CFM)
Fan design flow rate in cubic foot per minute (CFM)
FHPr
where: FHPr
Qr
=
=
P
=

=
fan
6356
=
=
Qr x P x 
fan x 6356
Fan horsepower (hp)
Average air flow rate for bin range in cubic foot per
minute (CFM)
System head for the bin range in inches of water
(“WG)
Density ratio of the gas to air in lbs/ft3; air is assumed
to have a density of 0.075 lbs/ft3
Fan efficiency at damper fully open
Conversion constant
kWhr =
where: kWhr
FHPr
=
=
=
FHPr x 0.746 x H
motor x VSD x belt/coupling
Energy consumption in the bin range
Fan horsepower (hp) calculated for the bin range
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 71 of 75
H
=
belt/coupling =
Number of operating hours in the bin range; this is
calculated by getting the percentage hours for the bin
range as dictated by the Operating Profile
Motor full load efficiency (decimal) x Motor efficiency
correction factor for VSD operation (decimal)
VSD efficiency factor (when operating with greater
than 40% load)
Belt/Coupling efficiency factor (decimal)
motor
=
VSD
=
0.746
Conversion constant from horsepower to kilowatt
=
The maximum summer and winter peak period demand (kW) savings are calculated by dividing the
Annual Energy Savings (kWh) by the total annual hours of operation.
6.1.6
Variable Speed Drive on Pumps
Savings calculations for Variable Speed Drive on Pumps are similar to the savings algorithm for the fans.
It starts with the calculation of the Annual Energy Savings (kWh), which is the difference between the
annual energy consumption (kWh) of the conventional pump system (base) and the pump system with
the VSD (retrofit). This calculation is done for each of the 10 bins representing 10 different percentage
flows.
For each bin in the conventional pump system, the pump horsepower (PHP) is calculated using the
following equation:
PHPb
=
Qb x P x 
pump x 3958
where: PHPb
Qb
=
=
P

pump
=
=
=
Pump horsepower (hp)
Average flow rate for bin range in U.S. gallons per
minute (USGPM)
Pump head for the bin range in feet
Specific gravity of the fluid; assume 1.0 for water
Pump efficiency at flow rate (decimal)
3958
=
Conversion constant
The conventional pump system energy consumption (kWh) for each bin is calculated using the following
equation:
kWhb =
where: kWhb
PHPb
H
=
=
=
PHPb x 0.746 x H
motor
Energy consumption in the bin range
Pump horsepower (hp) calculated for the bin range
Number of operating hours in the bin range; this is
calculated by getting the percentage hours for the bin
range as dictated by the Operating Profile
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 72 of 75
motor
=
0.746
=
Motor full load efficiency (decimal) x Motor efficiency
correction factor (decimal)
Conversion constant from horsepower to kilowatt
For Variable Speed Drive on Pumps, the annual energy consumption in kWh is calculated the same way
as the Conventional Pump System except that there is an additional definition for total head and
efficiencies.
= Ps + (Pd – Ps) ( Q / Qd ) 2
P
where: P
Ps
Pd
Q
=
=
=
=
Qd
=
System head for the bin range in feet
Static head for the pump system in feet
Design head (at X) in feet
Average flow rate for bin range in US gallons per
minute (USGPM)
Pump design flow rate in US gallons per minute
(USGPM)
PHPr
where: PHPr
Qr
=
=
P

pump
3958
=
=
=
=
=
Qr x P x 
pump x 3958
Pump horsepower (hp)
Average flow rate for bin range in US gallons per
minute (USGPM)
Pump head for the bin range in feet
Specific gravity of the fluid; assume 1.0 for water
Pump efficiency at design flow rate (decimal)
Conversion constant
kWhr =
where: kWhr
PHP
H
=
=
=
motor
=
VSD
=
0.746
=
PHP x 0.746 x H
motor x VSD
Energy consumption in the bin range
Pump horsepower (hp) calculated for the bin range
Number of operating hours in the bin range; this is
calculated by getting the percentage hours for the bin
range as dictated by the Operating Profile
Motor full load efficiency (decimal) x Motor efficiency
correction factor for VSD operation (decimal)
VSD efficiency factor (when operating with greater
than 40% load)
Conversion constant from horsepower to kilowatt
The maximum summer and winter peak period demand (kW) savings are calculated by dividing the
Annual Energy Savings (kWh) by the total annual hours of operation.
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 73 of 75
6.1.7
Unitary A/C
The energy performance of the Unitary A/C is determined by calculating the energy consumption of
both the existing (base case) and retrofit (design case) units for each hour that the equipment operates
during the year. First, peak (rated) power (watts) is calculated by dividing the capacity (Btu/hr) by the
energy efficiency ratio (EER). This amount is then converted to kilowatts.
Power consumption at part load is calculated using a methodology published by NRCan for use in a
building modeling software called EE49. This methodology is based on percentage unit output, wet bulb,
and dry bulb temperatures and it yields the percentage (%) of peak power consumed at part load. This
calculation is done for each hour of the year that operation is scheduled.
These hourly power consumption (kW) results are then simply summed to give the energy consumption
(kWh) over the desired period.
6.2
PROJECT ECONOMICS
The Project Economics section summarizes the estimated total annual savings in $/year based on the
cost information entered by the user. It also generates the amount of Participant Incentives that are
calculated based on the greater of $ 400.00/kW of Demand Savings or $ 0.05/kWh of Energy Savings for
lighting projects and the greater of $ 800.00/kW of Demand Savings or $ 0.10/kWh for non-lighting up
to a maximum of 50% of the total eligible costs for the project.
There are two highlighted cells (dark green) on the Outputs page that show the Demand Savings and
Energy Savings. The values in these two cells need to be entered in the saveONenergy RETROFIT
PROGRAM Application under the Site and Project Details of the Engineered Approach  Demand (kW)
and Energy (kWh) Savings.
The Project Economics section also automatically calculates the simple payback period with, and
without, the calculated incentive amount based on the total eligible project costs ($), the estimated
total annual savings ($/year) and the estimated Participant Incentive amount. Figure 54 shows an
example of a completed Project Economics section.
9
NRCan, 1999. Performance Compliance for Buildings, Appendix A. http://archive.nrccnrc.gc.ca/obj/irc/doc/pubs/nrcc46028.pdf
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 74 of 75
Figure 54 – Project Economics
6.3
QUALITY CONTROL (QC) AND DIAGNOSTICS FOR LDCS
The LDC Quality Control (QC) and Diagnostics section shows validations that can be used to help
identify whether the Energy and Demand Savings calculated are realistic with respect to the facility
consumption and maximum demand. To ensure the accuracy of the results, it is important that the
billing data found on the Applicant and Facility Info tab be completed. Figure 55 shows an example of
the LDC CQ & Diagnostics section filled in.
Figure 55 – LDC QC & Diagnostics
Included in this section is an analysis of how the average to maximum ratio compares to an average to
maximum threshold level identified by the LDC.
Technical User Guide Manual for the Retrofit Engineered Worksheets
JANUARY 2015
Page 75 of 75
APPENDIX A
Examples of Completed
Engineered Worksheets
RETROFIT COMBINED COMMERCIAL LIGHTING ENGINEERED WORKSHEET
A building in Toronto plans to retrofit its existing lighting system with more efficient lighting fixtures.
The facility’s lighting schedule is from 8:00 a.m. to 7:00 p.m. Mondays to Fridays. They are closed on
Saturdays and Sundays and during the regular statutory holidays. In addition, the facility has 2 days off
in the months of June and August.
Existing Lighting System:
x
x
20-1000W metal halide fixtures; input wattage = 1150 W/fixture;
150 acrylic lens troffer fixtures containing two lamps of 34W 4’T12; input wattage =
68W/fixture;
Proposed Lighting System:
x
x
25 LED high bay 3-lamp fixtures with a nominal wattage of 150 W per lamp; input wattage =
450W/fixture; mean lamp lumens = 42,300
90 acrylic lens troffer fixtures containing two lamps of 28W 4’T8; input wattage = 48W/fixture;
Calculation of Demand Savings (kW):
Base Case Power Input
Retrofit Power Input
Total Retrofit Power Input (kW)
Maximum Peak Period
Demand Savings (kW)
=
Total Connected Lighting
(Base)
15.840
-
Total Connected Lighting
(Retrofit)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 1 of 66
Maximum Peak Period
Demand Savings (kW)
=
Maximum Peak Period
Demand Savings (kW)
=
33.2 kW
-
15.570 kW
17.63 kW or 17.6 kW
Calculation of Energy Savings (kWh):
Annual Electricity
Consumption (kWh)
Maximum Peak Period
Demand Savings (kW)
=
x
Annual Operating Hours
The annual operating hours is located under the System Schedule tab.
Annual Electricity
Consumption (kWh)
=
Annual Electricity
Consumption (kWh)
=
17.63 kW
x
2695 hours
47,513 kWh
Calculation of Total Project Costs ($):
Project Cost Breakdown
Total costs of the equipment purchased (not including spare parts)
Total costs of labour for the installation of the equipment by suppliers
Total costs to dispose of or decommission the replaced equipment
Total costs of inspections of the Project as may be required pursuant
to Laws and Regulations
TOTAL ELIGIBLE COSTS FOR THE PROJECT
Amount
$ 22,000.00
$ 7,000.00
$29,000.00
Calculation of Incentives ($):
Calculated kW Participant Incentive ($400/kW of Demand Savings):
Participant Incentive
=
=
17.6 kW
x
$400/kW
$ 7,040.00
Calculated kWh Participant Incentive ($0.05/kW of Energy Savings)
Participant Incentive
=
=
47513 kWh
x
$ 0.05/kWh
$ 2,376.00
Maximum Allowable Participant Incentive (50% of Total Eligible Costs for the Project) = $4,8960.00
Therefore, Participant Incentive is $7,040.00
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 2 of 66
Version 5.0 - Retrofit Program - Commercial Combined Lighting Engineered Worksheet - May 12, 2014
OPERATING INFORMATION
Using the 24 hour 7 day table below, enter "1" if the equipment is scheduled to operate and "0" if the equipment is not scheduled to operate. Times during operation will illuminate purple.
These numbers are used in energy calculations, therefore if the time falls within the hour (i.e. 7:30), use your best estimate to choose the appropriate time.
Sun
Mon
Tue
Wed
Thu
Fri
Sat
0:00-0:59 am
0
0
0
0
0
0
0
1:00-1:59 am
0
0
0
0
0
0
0
2:00-2:59 am
0
0
0
0
0
0
0
3:00-3:59 am
0
0
0
0
0
0
0
4:00-4:59 am
0
0
0
0
0
0
0
5:00-5:59 am
0
0
0
0
0
0
0
6:00-6:59 am
0
0
0
0
0
0
0
7:00-7:59 am
0
0
0
0
0
0
0
8:00-8:59 am
0
1
1
1
1
1
0
9:00-9:59 am
0
1
1
1
1
1
0
10:00-10:59 am
0
1
1
1
1
1
0
11:00-11:59 am
0
1
1
1
1
1
0
12:00-12:59 pm
0
1
1
1
1
1
0
1:00-1:59 pm
0
1
1
1
1
1
0
2:00-2:59 pm
0
1
1
1
1
1
0
3:00-3:59 pm
0
1
1
1
1
1
0
4:00-4:59 pm
0
1
1
1
1
1
0
5:00-5:59 pm
0
1
1
1
1
1
0
6:00-6:59 pm
0
1
1
1
1
1
0
7:00-7:59 pm
0
0
0
0
0
0
0
8:00-8:59 pm
0
0
0
0
0
0
0
9:00-9:59 pm
0
0
0
0
0
0
0
10:00-10:59 pm
0
0
0
0
0
0
0
11:00-11:59 pm
0
0
0
0
0
0
0
Hour of Day
Adjust the number of weekdays (Mon-Fri) by month that the equipment is not operating due to statutory holidays, lieu days or scheduled shutdowns. The numbers pre-populated in the
table represent the default statutory holidays, per the table on the right.
Ontario Statutory, Civic and Other Holidays
January
1
February
1
New Years Day
January 1
March
0
Family Day
3rd Monday in February
April
2
Good Friday
Friday before Easter Sunday
May
1
Easter Monday
Monday after Easter Sunday
June
2
Victoria Day
Monday before May 25
July
1
Canada Day
July 1
August
3
Civic Holiday
1st Monday in August
September
1
Labour Day
1st Monday in September
October
1
Thanksgiving Day
2nd Monday in October
November
0
Christmas Day
December 25
December
2
Boxing Day
December 26
TOTAL:
15
55 This is the typical weekly number of operating hours for the equipment based on the schedule above (excluding holidays)
2695 This is the annual number of operating hours for the equipment based typical weekly and holiday schedule entered
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
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Official Mark of the Independent Electricity System Operator. Used under licence.
Combined Lighting Worksheet
System Schedule
Tab 3 of 5
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 3 of 66
Version 5.0 - Retrofit Program - Commercial Combined Lighting Engineered Worksheet - May 12, 2014
BASE CASE LIGHTING SYSTEM
Specify the existing application for the commercial lighting system (e.g. interior, high bay, etc) in the inputs below. Reference values for lamp and ballasts power can be found on the "Commercial Ballast Tables". For assistance with any of the fields, please click on the
appropriate row heading, which will display a pop-up comment
Fixtures
Lighting Application
Type of Fixture
Other Types of Fixture
Lamp Type
Manufacturer/Model Number
Nominal Lamp
Wattage (W)
Lamps Per
Fixture
Number of
Fixtures
Input Watts Per
Fixture (W)
Total Connected
Lighting Power
(kW)
1
HighBay
Other
Metal Halide Fixtures
20 - 1000W metal halide
fixtures
XYZ
1000
1
20
1150
23.000
2
Interior
Acrylic Lens Troffer
34W 4T12
XYZ
34
2
150
68
10.200
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Total Connected Lighting Power Per Zone (kW)
A mark of the Province of Ontario protected under Canadian trademark law.
Combined Lighting Worksheet
System Design Assumptions
Used under sublicence.
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Official Mark of the Independent Electricity System Operator. Used under licence.
33.200
Tab 4 of 5
Page 4 of 66
RETROFIT LIGHTING SYSTEM
Specify the retrofit application for the commercial lighting system (e.g. interior, high bay, etc) in the inputs below. Reference values for lamp and ballasts power can be found on the "Commercial Ballast Tables". For assistance with any of the fields', please click on the
appropriate row heading, which will display a pop-up comment
All technologies must meet applicable Code, standard and regulatory requirements including, but not limited to, CSA/cUL. It is the Applicant's responsibility to ensure that the technology is suitable (properly sized, etc.) to its intended application and to confirm that light
levels of the energy efficient design meet the minimum regulatory requirements and the suggested levels for the proposed use of the space. All products must be legal for sale in Canada.
For Applications submitted after October 1, 2012, LED lamps and luminaires must meet at least one of the following Measurement Approval criteria:
The product is approved and listed on the Energy Star Qualified Commercial Lighting List for bulbs 1 or fixtures2 or the product is approved and listed on the Design Lights Consortium List (DLC)3.
1
http://www.energystar.gov/index.cfm?fuseaction=find_a_product.showProductGroup&pgw_code=LB
Energy Star®-Bulbs
http://www.energystar.gov/index.cfm?fuseaction=find_a_product.showProductGroup&pgw_code=LTG
Energy Star®-Light Fixtures
3
http://www.designlights.org/
Design Lights Consortium
As may be updated from time to time by their respective organizations.
Other Types of
Fixtures
Lamp Type
Manufacturer/Model Number
Lighting Application
Type of Fixture
Fixture/Manufacturer/M
odel Number
25 LED high bay 3-lamp
LED
1
HighBay
ABC
fixture
2
2
Interior
Acrylic Lens Troffer
28W 4T8
ABC
Nominal Lamp
Wattage (W)
Lamps Per
Fixture
Number of
Fixtures
Input Watts per
Fixture (W)
Total Connected
Lighting Power
(kW)
150
3
25
450
11.250
28
2
90
48
4.320
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Total Connected Lighting Power Per Zone (kW)
15.570
ECONOMIC VALUES
$0.10
Blended Cost of Power ($/kWh)
A mark of the Province of Ontario protected under Canadian trademark law.
$6.00
Combined Lighting Worksheet
System Design Assumptions
Used under sublicence.
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Official Mark of the Independent Electricity System Operator. Used under licence.
Estimated Monthly Demand ($/kW)
Tab 4 of 5
Page 5 of 66
PROJECT COST BREAKDOWN
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and are limited to the following list. Enter the Eligible Costs below as applicable covering all
measures in this worksheet. Please note that a zone multiplier does not apply here.
$22,000.00
Total costs of the equipment purchased (not including spare parts)
$7,000.00
Total costs of labour for the installation of the equipment by suppliers
Total costs to dispose of or decommission the replaced equipment
Total costs of inspections of the Project as may be required pursuant to Laws and Regulations
$29,000.00
TOTAL ELIGIBLE COSTS FOR THE PROJECT
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour, service, administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by energy ratepayers or taxpayers in the Province of Ontario (other than funding principally directed to Social Housing Providers if, combined with
the Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates from manufacturers or wholesalers or other supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
A mark of the Province of Ontario protected under Canadian trademark law.
Combined Lighting Worksheet
System Design Assumptions
Used under sublicence.
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Tab 4 of 5
Page 6 of 66
Version 5.0 - Retrofit Program - Commercial Combined Lighting Engineered Worksheet - May 12, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the Energy Savings and Demand Savings associated with
implementing the energy efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
33.2
15.6
17.6
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
30.5
14.3
16.2
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
92%
92%
92%
Maximum Winter Peak Period Demand (kW)
33.2
15.6
17.6
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
22.6
10.6
12.0
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
68%
68%
68%
Annual Electricity Consumption (kWh)
89,474
41,961
47,513
PROJECT ECONOMICS
Based on cost information, entered by the user, along with incentive amounts, the project economics are summarized.
Assumed Blended Electricity Rate ($/kWh):
$
0.10
Assumed Demand Rate ($/kW)
$
6.00
Estimated Annual Energy Savings ($/year):
$
4,751
Other Savings (Cost) ($/year):
$
1,165
Estimated Total Annual Savings ($/year):
$
5,916
1
Demand Savings (kW) for the purpose of calculating the
Participant Incentive
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of the
Engineered Approach - Demand (kW) and Energy (kWh)
Savings
17.6
2
Energy Savings (kWh) for the purpose of calculating the
Participant Incentive
47,513
Total Eligible Costs for the Project($):
$
29,000
Calculated kW Participant Incentive ($400/kW of Demand Savings)
$
7,040
Calculated kWh Participant Incentive ($0.05/kWh of Energy Savings)
$
2,376
Estimated Participant Incentive Amount3,4:
$
7,040
Simple Payback (without Participant Incentive)
4.9
Simple Payback (with Participant Incentive)
3.7
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic, with respect to the facility consumption
Peak kW Savings - Percent of Facility Summer Peak Demand
13.5%
Facility Total kWh
Average kW Savings - Percent of Summer Peak Demand
12.3%
Max Summer kW
131
Percent of Facility Winter Peak Demand
13.4%
Max Winter kW
132
Average Savings - Percent of Winter Peak Demand
9.1%
Percent of Facility Total Annual Electricity Consumption
1.1%
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
92%
Average to Maximum Ratio exceeds Average to Maximum Threshold Level:
YES
4,187,654
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5 pm
on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount for this Engineering Worksheet is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant
Incentive.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project
Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the
basis for the 50% Project Cost Cap.
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Used under sublicence.
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Official Mark of the Independent Electricity System Operator. Used under licence.
Combined Lighting Worksheet
Outputs
Tab 5 of 5
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 7 of 66
RETROFIT LIGHTING CONTROLS ENGINEERED WORKSHEET
A 20-floor Office Building is installing occupancy sensors for 230 lighting fixtures consisting of two (2) T8
fluorescent lamps with a total input wattage of 51W in their meeting rooms. In addition, for meeting
rooms with big windows, they will be installing a combined daylighting and occupancy sensor for 200
lighting fixtures consisting of two (2) T8 fluorescent lamps with a total input wattage of 51W. The
facility operates its lighting system from 6:00 am to 10:00 p.m. Monday to Friday except holidays.
Existing Lighting System:
x
x
230 fixtures (2-lamp 28W T8 linear fluorescents)
200 fixtures (2-lamp 28W T8 linear fluorescents)
Proposed Lighting Control System:
x
x
Occupancy Sensor for 230 fixtures dimmable to 40%
Combined daylighting and occupancy sensor for 200 fixtures dimmable to 40%
Daylighting Information:
x
x
x
Daylight control type - On/off
Space window to wall ratio - 40
Window tint - light
Calculation of Demand Savings (kW):
Demand savings (kW) are derived from savings from the installation of the occupancy sensors and the
combined daylighting and occupancy sensors.
Demand Savings (kW) from the Occupancy Sensors
For each hour of the year and for each type of lighting control, the base case and efficiency case
wattages are calculated.
Base Case (kWb)
=
Wattage per fixture (kW) x No. of Fixtures
=
51 W / 1000 W/kW x 230
=
11.73 kW
The efficiency case wattage is calculated by summing up the controlled or reduced wattage due to the
lighting control and the fixed uncontrolled wattage.
Controlled Wattage (kWce)
=
Base Case (kWb) x (1 - % Dimmable) x (1 - % Savings)
=
11.73 kW x (1 - 0.40) x (1 - 0.4)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 8 of 66
=
Uncontrolled Wattage (kWue)
Efficiency Case (kWe)
Demand Savings (kW)
4.22 kW
=
Base Case (kWb) x % Dimmable)
=
11.73 kW x 0.40
=
4.69 kW
=
Controlled Wattage (kWce) + Uncontrolled Wattage (kWue)
=
4.22 + 4.69 = 8.91 kW
=
Base Case (kWb) - Efficiency Case (kWe)
=
11.73 - 8.91 = 2.82 kW
Demand Savings (kW) from the Combined Daylighting and Occupancy Sensors
Similarly, for each hour of the year and for each type of lighting control, the base case and efficiency
case wattages are calculated.
Base Case (kWb)
=
Wattage per fixture (kW) x No. of Fixtures
=
51 W / 1000 W/kW x 200
=
10.2 kW
Since the lighting control includes daylighting, the efficiency case is calculated for each hour using
daylight sensor savings derived from the parametric runs using eQuest for the on/off type. For this
example, the efficiency case for the summer peak period is shown.
Solving for the percentage daylight sensor savings during the summer peak period,
Tvis x Window-to-Wall Ratio (x)
% Savings (y)
=
0.6 x 40 = 24
=
-1.09E-09x6 + 2.2E-07x5 - 1.8E-05x4 + 0.000746x3 - 0.01692x2 + 0.200126x
=
-1.09E-09(24)6 + 2.2E-07(24)5 - 1.8E-05(24)4 + 0.000746(24)3 - 0.01692(24)2 +
0.200126(24)
=
0.983
Controlled Wattage (kWce)
=
Base Case (kWb) x (1 - % Dimmable) x (1 - % Savings from Combined
Daylighting and Occupancy) x (1 - % Savings from Occupancy Sensor)
=
10.2 kW x (1 - .40) x (1 - 0.984) x (1 - 0.40)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 9 of 66
=
Uncontrolled Wattage (kWue)
Efficiency Case (kWe)
Demand Savings (kW)
0.059 kW
=
Base Case (kWb) x % Dimmable)
=
10.2 kW x 0.40
=
4.08 kW
=
Controlled Wattage (kWce) + Uncontrolled Wattage (kWue)
=
0.059 + 4.08 = 4.14 kW
=
Base Case (kWb) - Efficiency Case (kWe)
=
10.2 - 4.14 = 6.06 kW
Total Demand Savings (kW)
=
Demand Savings from Occupancy Sensor + Demand Savings from
Combined Daylighting and Occupancy Sensor
=
2.8 kW + 6.1 kW = 8.9 kW
Calculation of Energy Savings (kWh):
The base case and retrofit case energy consumption (kWh) are obtained by summing up all the demand
(kW) for each hour for the whole 8760 hours. Base case energy consumption is 87,369 kWh while the
retrofit case energy consumption is 57,987 kWh. Energy savings, therefore, is 29,382 kWh.
Calculation of Total Project Costs ($):
It is assumed that the total project costs amount to $ 12,000.00 broken down as follows:
Lighting Control Cost
Labour Cost
Total:
$ 15,000.00
$ 2,000.00
$ 17,000.00
Calculation of Incentives ($):
Incentives are calculated based on $400/kW and $0.05/kWh. Based on this, the calculated Participant
Incentive based on demand savings is $3,560.00 and $1,469 based on energy savings. 50% Project Cost
is $8,500.00. Therefore, Participant Incentive is $3,560.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 10 of 66
Version 5.0 - Retrofit Program - Lighting Controls Engineered Worksheet - May 12, 2014
LIGHTING SYSTEM OPERATING SCHEDULE
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
Season 1
January
December
On Time
6:00 AM
6:00 AM
6:00 AM
6:00 AM
6:00 AM
Annual Holidays (#days)
Annual Operating Hours
Season 2
1
31
Off time
9:59 PM
9:59 PM
9:59 PM
9:59 PM
9:59 PM
<
<
<
<
<
<
<
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
On Time
Season 3
Off time
<
<
<
<
<
<
<
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
On Time
Off time
<
<
<
<
<
<
<
11
3984
SPACE INFORMATION
Select the applicable space type:
Room Length (feet)
10
Room Width (feet)
15
Conference/Meeting Room
Room area (sq. ft.)
150
LIGHTING INFORMATION
Enter the space lighting design. Use one row for each fixture type or to indicate different control of the same fixture. Only enter daylight
control for fixtures within 15 feet of the building perimeter. For example, the fixtures close to the building perimeter may have daylight sensor,
while fixtures further from the perimeter are controled via occupancy sensors.
Type of Fixture & Lamp
Lamps
Number of
Input Watts Per Dimmable to: fixtures
Fixture (W)
(%)
(#)
51
51
2 lamp T8 Fluorescents
2 lamp T8 Fluorescents
40%
40%
230
200
Lighting Control Type
Occupancy sensor
Daylight & Occupancy sensor
Fixtures with daylight control must be within 15 ft of the building perimeter
DAYLIGHTING INFORMATION
Select the applicable daylight control type:1
Space Window to Wall Ratio:
Select Window Tint:
On/off
40
Light
Window Tint Examples:
Clear
(Tvis = 0.8)
1
Light
(Tvis = 0.6)
Dark
(Tvis = 0.4)
Notes:
On/off - The daylight sensor turns the light off when there is adequate daylight. (OFF/100%)
Stepped dimming - The daylight sensor dims the light to track the available natural light via a series of output levels. (ie, OFF/30%/60%/100%)
Fully modulating dimming - The daylight sensor dims the light proportionally to the level of natural light available. (OFF to 100%)
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 11 of 66
Page 1 of 2
Version 5.0 - Retrofit Program - Lighting Controls Engineered Worksheet - May 12, 2014
ECONOMIC VALUES
$
0.10 Blended Cost of Power ($/kWh)
$
6.00
Estimated Monthly Demand ($/kW)
PROJECT COST BREAKDOWN
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and
implementation of the Eligible Measures and are limited to the following list. Enter the Eligible Costs below as applicable covering all
measures in this worksheet.
$
$
15,000.00 Total costs of the equipment purchased (not including spare parts)
2,000.00 Total costs of labour for the installation of the equipment by suppliers
Total costs to dispose of or decommission the replaced equipment
Total costs of inspections of the Project as may be required pursuant to Laws and Regulations
$
17,000.00 TOTAL ELIGIBLE COSTS FOR THE PROJECT
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour, service,
administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by energy
ratepayers or taxpayers in the Province of Ontario (other than funding principally directed to Social Housing Providers if, combined with the
Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates from manufacturers or wholesalers or other
supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 12 of 66
Page 2 of 2
Version 5.0 - Retrofit Program - Lighting Controls Engineered Worksheet - May 12, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the Energy Savings and Demand Savings associated with
implementing the energy efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
21.9
13.1
8.9
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
21.9
13.1
8.9
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
100%
100%
100%
Maximum Winter Peak Period Demand (kW)
21.9
15.4
6.5
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
21.9
15.4
6.5
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
100%
100%
100%
Annual Electricity Consumption (kWh)
87,369
57,987
29,382
PROJECT ECONOMICS
Based on cost information, entered by the user, along with incentive amounts, the project economics are summarized.
Assumed Blended Electricity Rate ($/kWh):
$
0.10
Assumed Demand Rate ($/kW)
$
6.00
Estimated Annual Energy Savings ($/year):
$
2,938
Other Savings (Cost) ($/year):
$
639
Estimated Total Annual Savings ($/year):
$
3,577
Demand Savings1(kW) for the purpose of calculating the
Participant Incentive
8.9
Energy Savings2 (kWh) for the purpose of calculating the
Participant Incentive
29,382
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy (kWh)
Savings
Total Eligible Costs for the Project($):
$
17,000
Calculated kW Participant Incentive ($400/kW of Demand Savings)
$
3,560
Calculated kWh Participant Incentive ($0.05/kWh of Energy Savings)
$
1,469
Estimated Participant Incentive Amount3,4:
$
3,560
Simple Payback (without Participant Incentive)
4.8
Simple Payback (with Participant Incentive)
3.8
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 13 of 66
Page 1 of 2
Version 5.0 - Retrofit Program - Lighting Controls Engineered Worksheet - May 12, 2014
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic, with respect to the facility consumption
Percent of Facility Summer Peak Demand
-
Facility Total kWh
Average kW Savings - Percent of Summer Peak Demand
-
Max Summer kW
-
Percent of Facility Winter Peak Demand
-
Max Winter kW
-
Average Savings - Percent of Winter Peak Demand
-
Percent of Facility Total Annual Electricity Consumption
-
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
100%
Average to Maximum Ratio exceeds Average to Maximum Threshold Level:
YES
-
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5 pm
on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant Incentive, with a Maximum Allowable
Participant Incentive at 50% of Total Eligible Costs for the Project.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project
Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the
basis for the 50% Project Cost Cap.
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 14 of 66
Page 2 of 2
RETROFIT COMPRESSED AIR ENGINEERED WORKSHEET
A company has a compressed air system consisting of five (5) compressors operating from 9:00 a.m. to
9:00 p.m. Mondays to Fridays and from 9:00 a.m. to 6:00 p.m. on Saturdays. The facility is closed on
Sundays and certain holidays. The existing compressor and motor information are as follows:
Existing Compressed Air System
A.C.#1
Compressor Designated Name
Manufacturer (CAGI Box 1)
A.C.#2
Main Unit
Please select
Model (CAGI Box 2)
Rated Capacity at Full Load
Operating Pressure (CAGI Box
3)
Full Load Operating Pressure
(CAGI Box 4)
Maximum Full Flow Operating
Pressure (CAGI Box 5)
Drive Motor Nominal Rating
(CAGI Box 6)
Total Package Input Power at
Zero Flow (CAGI Box 10)
Total Package Input Power at
Rated Capacity and Full Load
Operating Pressure (CAGI Box
11)
Typical Percent of Full Load
Operating Point (F.L.) *
Typical Operating Pressure
for this Compressor *
Operating Flow
Paint Line
Please select
R110I-A110
R551-A110
751
361
1,112
acfm (Total)
100
100
100.0
psig (Average)
110
110
110.0
psig (Average)
150
75
225
HP (Total)
36.8
20.0
56.8
kW (Total)
129.9
65.8
97.9
kW (Average)
90.0%
70.0%
80.0%
108.0
107.0
107.5
675.9
252.7
$
Percent Full Load
psig (Average)
928.6
cfm
179.3
kW
815,975
kWh
89,757
dollars
Proposed Energy Efficiency Measures:
The company is implementing the four measures included in the Compressed Air Engineered
Worksheet, namely:
Measure 1 – Reduce Air Leaks
Measure 2 - Reduce Operating Pressure
Measure 3 - Use Efficient Air Dryers
Measure 4 – Use Zero Loss Air Drains
Calculation of Energy Savings (kWh) for each Measure:
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 15 of 66
Measure 1 – Reduce Air Leakage
Information needed:
Target for Maximum Allowable Air Leaks and Non-Productive Air Use = 15.0 %
Dimensions of Air receiver tanks
Receiver Tank Diameter
(feet)
No. of
Similar
Receivers
(#)
Receiver Tank Height
(feet)
Air Receiver(s) - Type 1
1.0
5.0
Air Receiver(s) - Type 2
2.5
8.0
3
1
Dimensions of Distribution Pipes
Outside Pipe Diameter
(inches)
Pipe Length
(feet)
4.0
600
2.5
300
Largest Diameter Distribution Pipe
(Diameter and Length)
Second Largest Diameter
Distribution Pipe
(Diameter and Length)
Pressure Decay Test Results
Initial Pressure
(psig)
105.0
Final Pressure
(psig)
70.0
Time for Decay
(Seconds)
125
2
106.0
68.0
120
3
102.5
60.0
105
4
106.4
70.0
130
5
104.5
71.0
115
Average
104.9
67.8
119
Test Number
1
Volume of Air Receiver Tanks
Example for AC #1:
Tank Volume
3
(ft )
=
Outside Cylinder Diameter x
2
3.14 ft
x
Cylinder Height
(ft)
x
Quantity on Site
x
5.00
x
3.00
4
2
1.00
x
=
3.14
4
=
11.78 ft
3
Repeating the same calculation for AC #2 will yield a volume of 39.25 ft3.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 16 of 66
Volume of Largest Distribution Pipes
Example for AC #1:
2
Pipe Volume
3
(ft )
=
2
Outside Pipe Diameter (inch ) x 3.14
4
x
2
4.00
x
=
52.33 ft
Pipe Length (ft)
x
600
3.14
=
4
x
144
x
144
3
Repeating the same calculation for second distribution pipe will yield a volume of 10.22 ft3.
Total Volume of Air Receiver Tanks and Largest Distribution Pipes
Total Volume
of Piping and
3
Receivers (ft )
3
3
3
3
=
AC #1 Tank (ft )
+
AC #2 Tank (ft )
+
AC #1 Pipe (ft )
+
AC #2 Pipe (ft )
=
11.78
+
39.25
+
52.33
+
10.22
=
113.58 ft
3
Estimated Leakage and Non-Productive Air Losses (at 100% Compressor Flow Output)
Estimated Leakage at
100% Compressor
Flow Output (cfm)
=
1.25
x
Total Volume
of Piping and
Receivers
3
(ft )
=
1.25
x
113.58
=
181 cfm
x
x
Ending
Pressure
(psig)
Decay Time (min) x 14.7 psig
x
60
sec/min
(104.9 – 67.8) / (119 x 14.7)
x
60
Starting
Pressure (psig)
-
Operating Flow
Example for AC #1:
Operating Flow (cfm)
=
Rated Capacity at Full Load Operating
Pressure (acfm)
=
751 x 90%
=
675.9 cfm
x
Typical Percent of Full
Load Operating Point (%)
Repeating the same calculation for AC #2 will yield an operating flow of 675.9 cfm.
Estimated Air Leaks and Non-Productive Air Losses as Percentage of Normal Compressor Flow
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 17 of 66
Estimated Air Leaks as
Percentage of Normal
Compressor Flow (%)
=
Estimated Leakage at 100% Compressor
Flow Output (cfm)
Total Operating Flow (cfm)
=
( 181) / (675.9 + 252.7) x 100
=
19.4 %
x
100
Slope of Compressor Performance Line
Example with AC #1
Slope
=
Total Package Input Power at
Total Package Input Power at Zero
Rated Capacity (kW)
Flow (kW)
Rated Capacity at Full Load Operating Pressure (acfm)
=
(129.9 - 76.8) / 751
=
0.1240
Expected Power at Operating Flow and Design Pressure
Example with AC #1
Expected
Power
=
Total Package Input Power at
Zero Flow (kW)
=
36.8 + 0.1240 x 675.9
=
120.59 kW
+
Slope
x Operating Flow (kW)
Expected Power at Operating Flow and Actual Operating Pressure
Example for AC #1:
Power Demand at
Typical Operating
Level (kW)
=
1 -
Full Load
Operating
Pressure
(acfm)
-
Typical
Operating
Pressure for
Compressor
(psig)
=
[ 1 - ( 100.0 - 108.0 ) x 0.05 ] x 120.59
=
125.41 kW
x
0.05
x
Power Demand at
Operating Flow (kW)
Estimated annual kWh consumption per Air Compressor
Example for AC #1:
Energy Consumption of
Compressor at
Operating Level (kWh)
=
Power Demand at Typical Operating
Level (kW)
=
125.41 x 4551
=
570,757 kWh
x
Annual Operating Hours
(hrs)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 18 of 66
Estimated total annual kWh consumption
Annual Energy
= AC#1 Energy Consumption
Consumption for Air
of Compressor at
Compressors at Typical
Operating Level (kWh)
Operating Level (kWh)
= 570,757 + 245,217
=
Annual Energy
Savings (kWh)
=
+
AC#2 Energy Consumption of
Compressor at Operating
Level (kWh)
815,975 kWh
Estimated Air
Leaks (%)
-
Target
Allowable Leaks
(%)
=
(19.4% - 15.0%) x 815,975
=
36,270 kWh
Annual Energy Consumption for
Air Compressors at Typical
Operating Level (kWh)
x
A maintenance program is in place to ensure leaks are maintained. Hence, the annual energy savings by
repairing air leaks is discounted by 50%. Annual energy savings therefore is 18,135 kWh.
Estimated Annual Demand Savings from Reducing Air Leaks
Annual Demand
Savings (kW)
=
Annual Energy Savings (kWh)
Annual Operating Hours (hours)
=
36,270
4551
=
8.0 kW
A maintenance program is in place to ensure leaks are maintained. Hence, the annual demands savings
by repairing air leaks is discounted by 50%. Annual demands savings therefore is 4.0 kW.
Measure 2 – Reduce Discharge Pressure
Information needed:
Baseline calculations (see Measure 1 calculations)
Target for Average Air Discharge Pressure = 98 psig
Annual kWh Savings
Annual kWh
Savings
=
Average normal
operating discharge
pressure (psig)
-
Target pressure
(psig)
x
Annual Energy
Consumption
of
Compressors
(kWh)
-
Annual Energy
Savings from
Reduced Leaks
(kWh)
2 psig x 100
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 19 of 66
Annual kWh
Savings
=
107.5
Annual kWh
Savings
=
37,036 kWh
-
98.0
x
815,975 – 36,270
2 psig x 100
Annual kW Savings
Annual kW Savings
(kW)
Annual Energy Savings (kWh)
Annual Operating Hours (hours)
=
=
37,036
4551
=
8.1 kW
Similar to Measure 1, if the facility has a maintenance program that ensures that a reduced set point is
maintained, the Annual Energy Savings is discounted by 50%. Otherwise, it is discounted by 25%. In this
example the annual kW and kWh savings are discounted by 50%, resulting in savings of 4.1 kW and
18,518 kWh.
Measure 3 – Use Appropriate Dryer
Information needed:
Type of dryer currently employed = refrigerant or desiccant dryers
Amount of flow allocated to each Dryer = 500 cfm and 200 cfm
Tested flows for each of the dryer at 100% and 10% output
Each Dryer’s Total Input Power
Base Case Dryer 1 Power (Refrigerant Example)
Base Case
Dryer 1
Power
(kW)
Dryer
Input
Power at
10% Flow
of Existing
Dryer (kW)
=
=
=
7.2
+
Amount of
Flow
Allocated
to Dryer #1
(cfm)
+
500
-
131
-
Tested 10%
Flow (CAGI Box
6 for
Refrigerant
Dryers) (cfm)
x
7.4
981
x
Dryer Input
Power at
100% Flow of
Existing Dryer
(kW)
Tested
Existing Flow
at 100% (cfm)
-
-
-
Dryer
Input
Power at
10% Flow
of Existing
Dryer (kW)
Tested
Existing
Flow at
10% (cfm)
7.2
131
7.29 kW
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 20 of 66
A similar calculation is applied to generate a value for the power consumed by the Proposed Case
Dryers. Repeating the calculation for Proposed Case Dryer 1 and 2 would yield the values 3.0 kW and 2.1
kW respectively.
Base Case Dryer 2 Power (Desiccant Example)
Base Case Dryer 2
Power (kW)
Amount of Flow Allocated to Dryer
#2 (cfm)
100
=
=
200 / 100 x 2.5
=
5 kW
x
2.5
(kW/cfm)
Base Case Total Dryer Power
Base Case Total Dryer
Power (kW)
=
=
Base Case Dryer 1 Power
(kW)
7.29 + 5.00
=
12.29 kW
+
Base Case Dryer 2 Power
(kW)
Repeating a similar calculation for the Proposed Case Total Dryer Power (kW) yields 5.10 kW.
Annual kW Demand Savings
Annual kW Demand
Savings (kW)
=
Base Case Total Dryer Power
(kW)
=
12.29 - 5.10
=
7.2 kW
-
Proposed Case Dryer
(kW)
Base Case Dryer Energy Consumption (kWh)
Base Case Dryer Energy
Consumption (kWh)
=
Base Case Total Dryer Demand
(kW)
=
12.29 x 4551
=
55,932 kWh
x
Annual Operating Hours (hours)
Repeating a similar calculation for the Proposed Case Dryer Energy Consumption (kWh) yields 23.210
kWh.
Annual kWh Energy Savings
Annual kWh Energy
Savings (kWh)
=
Base Case Dryer (kWh)
-
Proposed Case Dryer (kWh)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 21 of 66
=
55,932 - 23,210
=
32,722 kWh
Measure 4 – Zero Loss Drain
Information needed:
Annual
Energy
Savings
(kWh)
Compressed Air System Operating Hours per Year = 4551
Blended Cost of Power = $0.11/kWh
Seeking Incentive for this quantity of Zero Loss Drains = 3
Average drain blowdown time between cycles = 15 seconds
Average time between blowdown cycles = 2 minutes
Average drain
blowdown time
between cycles (s)
x
=
15
x
=
19,781 kWh
=
Compressed Air
System Operating
Hours per Year (hr)
Average time
between blowdown
cycle (min)
x
4551 / 2
x
0.02125
x
Seeking Incentive
for this quantity of
Zero Loss Drains
Blended Cost of
Power ($/kWh)
0.02125
X
3 / 0.11
Annual kW Savings
Annual kW Savings
(kW)
=
Annual Energy Savings (kWh)
Compressed Air System Operating
Hours per Year (hr)
=
19,781
4551
=
4.3 kW
Total Annual Energy Savings
Total Annual
Energy
Savings (kWh)
=
Annual Energy
Savings from
Measure 1
(kWh)
=
18,135
=
89,156 kWh
+
Annual Energy
Savings from
Measure 2
(kWh)
+
18,518
+
Annual Energy
Savings from
Measure 3
(kWh)
+
Annual Energy
Savings from
Measure 4 (kWh)
+
32,722
+
19,781
A similar calculation is applied to Total Annual Demand Savings, which yields a value of 19.6 kW.
Calculation of Total Project Costs ($):
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 22 of 66
Total Project Costs ($) are calculated from the summation of the total eligible project costs of each
measure shown in the individual measures tab.
Total Project
Costs ($)
=
Total Eligible
Project Cost for
Measure 1 ($)
+
Total Eligible
Project Cost for
Measure 2 ($)
+
Total Eligible
Project Cost for
Measure 3 ($)
+
Total Eligible
Project Cost for
Measure 4 ($)
=
1,547
+
1,593
+
27,000
+
1,825
=
$ 31,965
Calculation of Incentives ($):
In calculating the Participant Incentives, $800/kW and $0.10 incentive rates are used for compressed air
measures.
Calculated kW Participant Incentive ($800/kW of Demand Savings):
Participant Incentive
=
19.6 kW
=
$ 15,672.00
x
$ 800/kW
Calculated kWh Participant Incentive ($0.10/kW of Energy Savings)
Participant Incentive
=
89,156 kWh
=
$ 8,915.58
x
$ 0.10/kWh
Participant Incentive based on kW savings $ (15,672.00) is greater than the Participant Incentive based on
kWh savings ($8,915.58). Therefore, $15,672.00 is selected.
A cap is placed on the Participant Incentives as 50% of the total eligible project costs. 50% of the total
eligible project costs in this scenario is $15,982.50. As this value is higher than Participant Incentives
selected, no change is required.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 23 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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Next Step
OPERATING INFORMATION
Using the 24 hour 7 day table below, enter "1" if the equipment is scheduled to operate and "0" if the equipment is not scheduled to operate. Times during operation will illuminate purple.
These numbers are used in energy calculations therefore if the time falls within the hour (i.e. 7:30) use your best estimate to choose the appropriate time.
Sun
Mon
Tue
Wed
Thu
Fri
Sat
0:00-0:59 am
0
0
0
0
0
0
0
1:00-1:59 am
0
0
0
0
0
0
0
2:00-2:59 am
0
0
0
0
0
0
0
3:00-3:59 am
0
0
0
0
0
0
0
4:00-4:59 am
0
0
0
0
0
0
0
5:00-5:59 am
0
0
0
0
0
0
0
6:00-6:59 am
0
1
1
1
1
1
0
7:00-7:59 am
0
1
1
1
1
1
0
8:00-8:59 am
0
1
1
1
1
1
0
9:00-9:59 am
0
1
1
1
1
1
0
10:00-10:59 am
0
1
1
1
1
1
1
11:00-11:59 am
0
1
1
1
1
1
1
12:00-12:59 pm
0
1
1
1
1
1
1
1:00-1:59 pm
0
1
1
1
1
1
1
2:00-2:59 pm
0
1
1
1
1
1
1
3:00-3:59 pm
0
1
1
1
1
1
1
4:00-4:59 pm
0
1
1
1
1
1
0
5:00-5:59 pm
0
1
1
1
1
1
0
6:00-6:59 pm
0
1
1
1
1
1
0
7:00-7:59 pm
0
1
1
1
1
1
0
8:00-8:59 pm
0
1
1
1
1
1
0
9:00-9:59 pm
0
1
1
1
1
1
0
10:00-10:59 pm
0
1
1
1
1
1
0
11:00-11:59 pm
0
0
0
0
0
0
0
Hour of Day
Adjust the number of weekdays (Monday-Friday) by month that the equipment is not operating due to statutory, civic or other holidays, lieu days or scheduled shutdowns. The numbers
pre-populated in the table represent the default statutory, civic or other holidays, per the table on the right.
Ontario Statutory, Civic or Other Holidays
January
1
February
1
New Years Day
January 1
March
0
Family Day
3rd Monday in February
April
2
Good Friday
Friday before Easter Sunday
May
1
Easter Monday
Monday after Easter Sunday
June
0
Victoria Day
Monday before May 25
July
1
Canada Day
July 1
August
1
Civic Holiday
1st Monday in August
September
1
Labour Day
1st Monday in September
October
1
Thanksgiving Day
2nd Monday in October
November
0
Christmas Day
December 25
December
2
Boxing Day
December 26
TOTAL:
11
91 This is the typical weekly number of operating hours for the equipment based on the schedule above (excluding holidays)
4551 This is the annual number of operating hours for the equipment based typical weekly and holiday schedule entered
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Compressed Air Worksheet
System Schedule
Tab 3 of 11
Page 24 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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ANNUAL OPERATING HOURS AND UNIT COST OF POWER
Compressed Air System Operating Hours per Year
Blended Cost of Power
Estimated Monthly Peak Demand Unit Cost
4,551 Hours
0.1100 $/kWh
5.50 $/kW
$
$
AIR COMPRESSORS
Compressor Designated Name
Manufacturer (CAGI Box 1)
Model (CAGI Box 2)
A.C.#1
Main Unit
A.C.#2
Paint Line
Please select
Please select
A.C.#3
A.C.#4
A.C.#5
Please select
Please select
Please select
R110I-A110
R551-A110
751
361
Rated Capacity at Full Load Operating Pressure (CAGI Box 3)
100
100
Full Load Operating Pressure (CAGI Box 4)
Maximum Full Flow Operating Pressure (CAGI Box 5)
110
110
150
75
Drive Motor Nominal Rating (CAGI Box 6)
36.8
20.0
Total Package
g Input
p Power at Zero Flowp(CAGI
y Box 10)
p
g
129.9
65.8
Pressure (CAGI Box 11)
Typical Percent of Full Load Operating Point (F.L.) *
90.0%
70.0%
Typical Operating Pressure for this Compressor *
108.0
107.0
Operating Flow
675.9
252.7
Power Demand for Air Compressors at Typical Operating Level
(See below for Warning Message) Annual Energy Consumption for Air Compressors at Typical Operating Level
Annual Energy Cost for Air Compressors $
1,112
100
110.0
225
56.8
97.9
80.0%
107.5
928.6
179.3
815,975
89,757
acfm (Total)
psig (Average)
psig (Average)
HP (Total)
kW (Total)
kW (Average)
Percent Full Load
psig (Average)
acfm
kW
kWh
dollars
Please provide an explanation below about methods used to determine the Typical Percent of Full Load Operating Point and Typical Operating Pressure Values.
Based on operating logs.
OK
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Compressed Air Worksheet
Compressor Inventory
Tab 4 of 11
Page 25 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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SYSTEM VOLUME OF MAIN DISTRIBUTION PIPES AND RECEIVER TANKS
For Step 1 of the air leakage estimate, enter dimensions of the main distribution pipes and air receiver tanks.
Outside Pipe
Diameter
(inches)
Largest Diameter Distribution Pipe (Diameter and Length)
Second Largest Diameter Distribution Pipe (Diameter and Length)
Air Receiver(s) - Type 1
Air Receiver(s) - Type 2
Air Receiver(s) - Type 3
Air Receiver(s) - Type 4
Air Receiver(s) - Type 5
Pipe Length
(feet)
4.0
2.5
600
300
Receiver Tank
Diameter (feet)
Receiver Tank
Height (feet)
Volume
Units
52.3 ft3
10.2 ft3
No. of Similar
Receivers (#)
1.0
5.0
3
2.5
8.0
1
Total Volume of Receivers and Large Pipes
Volume
Units
11.8
39.3
114
ft3
ft3
ft3
ft3
ft3
ft3
PRESSURE DECAY TEST
For Step 2 of the air leakage estimate, enter the results of five (5) pressure decay tests below.
The highest possible pressure for the decay test (based on the
110.0
compressors) is:
Starting
Ending Pressure Time for Decay
Pressure (psig)
(psig)
Test (seconds)
Test Results #1
Test Results #2
Test Results #3
Test Results #4
Test Results #5
Test Average
105.0
106.0
102.5
106.4
104.5
104.9
70.0
68.0
60.0
70.0
71.0
67.8
125
120
105
130
115
119
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Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Compressed Air Worksheet
Pipe Volume & Pressure Test
Tab 5 of 11
Page 26 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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MEASURE #1 - REDUCE AIR LEAKS AND NON-PRODUCTIVE COMPRESSED AIR USE
Please review the "Start Here" tab to determine if the project qualifies to use this Worksheet as well as the information or data to have on hand when completing the Worksheet.
Demand and energy savings will default to zero if no explanation is provided for Compressor Loading (Cell A23) and/or Operating Pressure (Cell A24) found under the Compressor
Inventory tab.
Intention to Reduce Air Leaks (as selected on 'Start Here' Tab)?
Commitment to repair and maintain Targeted Allowable Air Leaks for Stipulated period if applying for incentive?
Estimated Leakage and Non-Productive Air Losses (at 100% Compressor Flow Output)
Estimated Air Leaks and Non-Productive Air Losses as Percentage of Normal Compressor Flow
Target for Maximum Allowable Air Leaks and Non-Productive Air Use (10% or less is best practice)
Estimated Annual Energy Losses through Air Leaks and Non-Productive Air Usage
Estimated Annual Cost of Air Leaks and Non-Productive Air Usage
Estimated Air Leaks at Target Leak Level
Required Reduction in Air Leaks to Meet Target
Estimated Annual Energy Savings from Reducing Air Leaks to Targeted Amount
Estimated Annual Demand Savings from Reducing Air Leaks
Yes
Yes
181
19.4%
15.0%
158,667
17,453
139
41
36,270
8.0
From "Start Here" Tab
cfm
percent
percent
kWh
dollars
cfm
cfm
kWh
kW
MEASURE #1 - COST, ESTIMATED INCENTIVE AND PAYBACK
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and
are limited to the following list. Please enter the Eligible Costs below as applicable.
Actual costs of the equipment purchased and installed $
1,000.00 dollars
Actual costs of labour for the installation of the equipment by suppliers $
Actual costs of dispose of or decommission the replaced equipment $
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations $
TOTAL ELIGIBLE COSTS FOR THE PROJECT $
500.00 dollars
dollars
47.00 dollars
1,547.00 dollars
Permanence Factor for Measure
Adjusted Energy Savings for this Measure
50% percent
18,135 kWh
Adjusted Demand Savings for this Measure
Estimated Annual Cost Savings (based on Adjusted Energy Savings) $
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V 5.0
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
3.98 kW
1,995 dollars
Compressed Air Worksheet
1 Reduce Leaks
Tab 6 of 11
Page 27 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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MEASURE #2 - REDUCE COMPRESSOR SYSTEM DISCHARGE PRESSURE IF VIABLE
Please review the "Start Here" tab to determine if the project qualifies to use this Worksheet as well as the information or data to have on hand when completing the Worksheet. Demand
and energy savings will default to zero if no explanation is provided for Compressor Loading (Cell A23) and/or Operating Pressure (Cell A24) found under the Compressor Inventory tab.
Intention to Reduce System Discharge Pressure (as selected on 'Start Here' Tab)?
Commitment to operate at Target Discharge Pressure for stipulated period if applying for incentive?
Typical Average Existing Air Discharge Pressure
Target for Average Air Discharge Pressure
Estimated Annual Energy Savings from Reducing Air Pressure to Targeted Amount
Yes From "Start Here" Tab
Yes
107.5 psig
98.0 psig
37,036 kWh
MEASURE #2 - COST, ESTIMATED INCENTIVE AND PAYBACK
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and are
limited to the following list. Please enter the Eligible Costs below as applicable.
Actual costs of the equipment purchased and installed $
1,000.00 dollars
Actual costs of labour for the installation of the equipment by suppliers $
500.00 dollars
Actual costs of dispose of or decommission the replaced equipment $
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations $
60.00 dollars
33.00 dollars
TOTAL ELIGIBLE COSTS FOR THE PROJECT $
Permanence Factor for Measure
Adjusted Energy Savings for this Measure
Adjusted Demand Savings for this Measure
Estimated Annual Cost Savings (based on Adjusted Energy Savings) $
1,593.00 dollars
50% percent
18,518 kWh
4.1 kW
2,037 dollars
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Compressed Air Worksheet
2 Reduce Pressure
Tab 7 of 11
Page 28 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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MEASURE #3 - USE ENERGY EFFICIENT AIR DRYER(S)
Please review the "Start Here" tab to determine if the project qualifies to use this Worksheet as well as the information or data to have on hand when completing the
Worksheet. Demand and energy savings will default to zero if no explanation is provided for Compressor Loading (Cell A23) and/or Operating Pressure (Cell A24)
found under the Compressor Inventory tab.
Intention to install at least one energy efficient air dryer?
Yes
Is the required dewpoint to be ABOVE 32°F (or 0°C)?
Yes
Total Compressed Air Operating Flow (scfm)
929
From "Start Here" Tab
Eligible to convert from Desiccant to Refrigerant OR from Refrigerant to more
efficient Refrigerant Dryer
EXISTING AND PROPOSED AIR DRYERS
Amount of Flow Allocated to Dryer #1 (cfm)
Existing Dryer #1 Type (Refrigerant or Desiccant)
Manufacturer (CAGI Box 1 for Refrigerant Dryers)
Model Number (CAGI Box 3 for Refrigerant Dryers)
Cycling /Non-Cycling (CAGI Box 4 for Refrigerant Dryers)
Tested Flow (CAGI Box 6 for Refrigerant Dryers)
Outlet Pressure Dewpoint (CAGI Box 7 for Refrigerant Dryers)
Pressure Drop (CAGI Box 8 for Refrigerant Dryers)
Total Dryer Input Power (CAGI Box 9 for Refrigerant Dryers)
Power Requirement for Dryer
Amount of Untreated Air for Remaining Dryer(s)
Amount of Flow Allocated to Dryer #2 (cfm)
Existing Dryer #2 Type (Refrigerant or Desiccant)
Manufacturer (CAGI Box 1 for Refrigerant Dryers)
Model Number (CAGI Box 3 for Refrigerant Dryers)
Cycling /Non-Cycling (CAGI Box 4 for Refrigerant Dryers)
Tested Flow (CAGI Box 6 for Refrigerant Dryers)
Outlet Pressure Dewpoint (CAGI Box 7 for Refrigerant Dryers)
Pressure Drop (CAGI Box 8 for Refrigerant Dryers)
Total Dryer Input Power (CAGI Box 9 for Refrigerant Dryers)
Power Requirement for Dryer
Amount of Untreated Air for Remaining Dryer(s)
Amount of Flow Allocated to Dryer #3 (cfm)
Existing Dryer #3 Type (Refrigerant or Desiccant)
Manufacturer (CAGI Box 1 for Refrigerant Dryers)
Model Number (CAGI Box 3 for Refrigerant Dryers)
Cycling /Non-Cycling (CAGI Box 4 for Refrigerant Dryers)
500
Refrigerant
Fill Up Existing and Proposed Dryer Sections
Existing Dryer #1
Proposed Dryer
Ingersoll Rand
Ingersoll Rand
D1700INA400
NVC1000W400
Please select
Cycling Refrigerant
Full Flow
981
39
2.5
7.4
429
Full Flow
1014
39
2.5
5.73
7.3
cfm
10% Flow
160
39
0.33
1.2
3.0
Units
cfm
psig
psig
kW
kW
200
Desiccant
Fill Up Proposed Dryer Section but not Existing Dryer Section
Existing Dryer #2
Proposed Dryer #2
Zeks
Zeks
500NCEA400
200HSGA400
Please select
Cycling Refrigerant
Full Flow
500
39
3
3.7
229
10% Flow
50
39
0.1
3.6
Full Flow
200
39
1.6
2.1
5.0
cfm
10% Flow
20
39
0.1
0.54
2.1
Units
cfm
psig
psig
kW
kW
0
Please select
Fill Up Existing and Proposed Dryer Sections
Existing Dryer #3
Proposed Dryer #3
Please select
Please select
Please select
Full Flow
Tested Flow (CAGI Box 6 for Refrigerant Dryers)
Outlet Pressure Dewpoint (CAGI Box 7 for Refrigerant Dryers)
Pressure Drop (CAGI Box 8 for Refrigerant Dryers)
Total Dryer Input Power (CAGI Box 9 for Refrigerant Dryers)
Power Requirement for Dryer
Amount of Untreated Air for Remaining Dryer(s)
10% Flow
131
39
0.33
7.2
229
10% Flow
0.0
cfm
Please select
Full Flow
10% Flow
0.0
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Units
cfm
psig
psig
kW
kW
Compressed Air Worksheet
3 Air Dryer
Tab 8 of 11
Page 29 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
Amount of Flow Allocated to Dryer #4 (cfm)
Existing Dryer #4 Type (Refrigerant or Desiccant)
0
Please select
Fill Up Existing and Proposed Dryer Sections
Existing Dryer #4
Proposed Dryer #4
Please select
Please select
Manufacturer (CAGI Box 1 for Refrigerant Dryers)
Model Number (CAGI Box 3 for Refrigerant Dryers)
Cycling /Non-Cycling (CAGI Box 4 for Refrigerant Dryers)
Please select
Full Flow
Tested Flow (CAGI Box 6 for Refrigerant Dryers)
Outlet Pressure Dewpoint (CAGI Box 7 for Refrigerant Dryers)
Pressure Drop (CAGI Box 8 for Refrigerant Dryers)
Total Dryer Input Power (CAGI Box 9 for Refrigerant Dryers)
Power Requirement for Dryer
Amount of Untreated Air for Remaining Dryer(s)
Amount of Flow Allocated to Dryer #5 (cfm)
Existing Dryer #5 Type (Refrigerant or Desiccant)
229
Please select
10% Flow
Full Flow
0.0
cfm
10% Flow
Units
cfm
psig
psig
kW
kW
0.0
0
Please select
Fill Up Existing and Proposed Dryer Sections
Existing Dryer #5
Proposed Dryer #5
Please select
Please select
Manufacturer (CAGI Box 1 for Refrigerant Dryers)
Model Number (CAGI Box 3 for Refrigerant Dryers)
Cycling /Non-Cycling (CAGI Box 4 for Refrigerant Dryers)
Please select
Full Flow
Tested Flow (CAGI Box 6 for Refrigerant Dryers)
Outlet Pressure Dewpoint (CAGI Box 7 for Refrigerant Dryers)
Pressure Drop (CAGI Box 8 for Refrigerant Dryers)
Total Dryer Input Power (CAGI Box 9 for Refrigerant Dryers)
Power Requirement for Dryer
Residual Amount of Untreated Air
229
Please select
10% Flow
Full Flow
0.0
cfm
10% Flow
Units
cfm
psig
psig
kW
kW
0.0
DRYER TECHNICAL SUMMARY
Dryer Summary
Dryer #1
Existing Dryer
Type
Base Case
(kW)
Proposed
Case (kW)
Refrigerant
7.3
3.0
New Dryer
Type
Cycling
Refrigerant
Allocated
Flow
Untreated Air
500
429
200
229
Dryer #2
Desiccant
5.0
2.1
Cycling
Refrigerant
Dryer #3
-
-
-
-
-
229
Dryer #4
-
-
-
-
-
229
Dryer #5
-
-
-
-
-
229
Totals
-
12.3
5.1
-
700
229
Notes:
Dryer capacity or allocated amounts may be insufficient to treat air produced by compressors
MEASURE #3 - COST, ESTIMATED INCENTIVE AND PAYBACK
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible
Measures and are limited to the following list. Please enter the Eligible Costs below as applicable.
Actual costs of the equipment purchased and installed
Actual costs of labour for the installation of the equipment by suppliers
Actual costs of dispose of or decommission the replaced equipment
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations
TOTAL ELIGIBLE COSTS FOR THE PROJECT
Permanence Factor for Measure
Adjusted Energy Savings for this Measure
Adjusted Demand Savings for this Measure
Estimated Annual Cost Savings (based on Adjusted Energy Savings)
$
$
$
$
$
$
22,000.00
3,000.00
1,500.00
500.00
27,000.00
100%
32,722
7.2
3,599
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
dollars
dollars
dollars
dollars
dollars
percent
kWh
kW
dollars
Compressed Air Worksheet
3 Air Dryer
Tab 8 of 11
Page 30 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
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MEASURE #4 - USE ZERO LOSS CONDENSATE DRAINS
Please review the "Start Here" tab to determine if the project qualifies to use this Worksheet as well as the information or data to have on hand when completing the Worksheet. Demand
and energy savings will default to zero if no explanation is provided for Compressor Loading (Cell A23) and/or Operating Pressure (Cell A24) found under the Compressor Inventory tab.
Intention to Install Zero Air Loss Drains?
Total Quantity of ALL Drains upstream of Dryers including those used for Dryers
Total Quantity of Existing Zero Loss Air Dryers in Above Quantity
Eligible Quantity of Zero Loss Air Drains
Seeking Incentive for this quantity of Zero Loss Drains
Average drain blowdown time between cycles
Average time between blowdown cycles
Estimated per Unit Cost for Zero Loss Drains
$
Yes
6
3
3
3
15
2
250.00
From "Start Here" Tab
Quantity
Quantity
Quantity
seconds
minutes
MEASURE #4 - COST, ESTIMATED INCENTIVE AND PAYBACK
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and are
limited to the following list. Please enter the Eligible Costs below as applicable.
Actual costs of the equipment purchased and installed
Actual costs of labour for the installation of the equipment by suppliers
Actual costs of dispose of or decommission the replaced equipment
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations
TOTAL ELIGIBLE COSTS FOR THE PROJECT
$
$
$
$
$
Permanence Factor for Measure
Adjusted Energy Savings for this Measure
Adjusted Demand Savings for this Measure
Estimated Annual Cost Savings (based on Adjusted Energy Savings) $
750.00
1,000.00
50.00
25.00
1,825.00
100%
19,781
4.3
2,176
dollars
dollars
dollars
dollars
dollars
percent
kWh
kW
dollars
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Compressed Air Worksheet
4 Zero Loss Drains
Tab 9 of 11
Page 31 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
Navigation Page
SUMMARY OF MEASURES, ENERGY IMPACT, PROJECT ECONOMICS & INCENTIVES
MEASURE #1 - REDUCE AIR LEAKS AND NON-PRODUCTIVE COMPRESSED AIR USE
Intention to Implement
Intention to Sustain Leak Management Program
Estimated Air Leaks
Estimated Air Leaks (Based on Typical Flow)
Target for Maximum Air Leaks (set by Applicant)
Air Leaks if Leak Reduction Target is Met
Yes
Yes
180.6
19.4%
15.0%
139.3
scfm
percent
percent
scfm
MEASURE #2 - REDUCE COMPRESSOR SYSTEM DISCHARGE PRESSURE IF VIABLE
Intention to Implement
Intention to Sustain Pressure Reduction Program
Typical Average Existing Air Discharge Pressure
Target New Discharge Pressure (set by Applicant)
Yes
Yes
107.5 psig
98.0 psig
MEASURE #3 - USE ENERGY EFFICIENT AIR DRYER(S)
Intention to Implement
Is the Required Dewpoint to be ABOVE 32°F (or 0°C)?
Existing Air Dryers
Yes
Yes
Manufacturer
Model
Cycling or Non-Cycling
Dryer #1
Dryer #2
Dryer #3
Dryer #4
Dryer #5
Proposed Air Dryers
Ingersoll Rand
Zeks
Please select
Please select
Please select
Manufacturer
D1700INA400
500NCEA400
Model
Please select
Please select
Please select
Please select
Please select
Cycling or Non-Cycling
Dryer #1
Dryer #2
Dryer #3
Dryer #4
Dryer #5
Ingersoll Rand
Zeks
Please select
Please select
Please select
NVC1000W400
200HSGA400
-
Cycling Refrigerant
Cycling Refrigerant
-
MEASURE #4 - USE ZERO LOSS CONDENSATE DRAINS
Intention to Implement
Number of Eligible Drains
Number of new Zero Loss Drains
Yes
3
3
ENERGY IMPACT, PROJECT ECONOMICS AND INCENTIVE SUMMARY
Measure #2 Measure #4Measure #3Reduce
Zero Loss
Efficient Dryers
Pressure
Drains
36,270
37,036
32,722
19,781
8.0
8.1
7.2
4.3
1,547 $
1,593 $
27,000 $
1,825 $
50%
50%
100%
100%
18,135
18,518
32,722
19,781
4.0
4.1
7.2
4.3
1,995 $
2,037 $
3,599 $
2,176 $
Measure #1 Reduce Leaks
Gross kWh Savings
Gross kW Reduction
TOTAL ELIGIBLE COSTS FOR THE PROJECT
Permanence Factor for Measure
Adjusted Energy Savings for this Measure
Adjusted Demand Savings for this Measure
Estimated Annual Cost Savings (based on Adjusted Energy Savings)
$
$
Estimated Base Case Annual Energy Consumption
Estimated Base Case Peak Demand while Operating
Efficient Case Annual Energy Consumption
Estimated Efficient Case Peak Demand while Operating
Percent Energy Savings Identified
Units
Totals
125,809 kWh
27.6 kW
31,965 dollars
percent
89,156 kWh
19.6 kW
9,807 dollars
871,907
191.6
782,751
172.0
10.2%
kWh
kW
kWh
kW
Percent
CAUTIONARY MESSAGES
Based on operating logs.
Eligible to convert from Desiccant to Refrigerant OR from Refrigerant to more efficient Refrigerant Dryer
Dryer capacity or allocated amounts may be insufficient to treat air produced by compressors
Ratio of drain blowdown time to cycle time between blowdowns is not typical
CONDITIONS AND DISCLAIMERS
Note 1: Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures
and are limited to the following list. Please enter the Eligible Costs below as applicable.
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour, service, administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by energy ratepayers or taxpayers in the Province of Ontario
(other than funding principally directed to Social Housing Providers if, combined with the Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates
from manufacturers or wholesalers or other supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
Compressed Air Worksheet
A mark of the Province of Ontario protected under Canadian trademark law.
Summary
Used under sublicence.
OM
Tab 10 of 11
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 32 of 66
Version 5.0 - Retrofit Program - Compressed Air Engineering Worksheet - September 12, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the savings associated with implementing the energy efficient
option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
191.6
172.0
19.6
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
184.8
184.8
0.0
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
96%
107%
N/A
Maximum Winter Peak Period Demand (kW)
191.6
172.0
19.6
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
182.5
163.8
18.7
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
95%
95%
95%
Annual Electricity Consumption (kWh)
871,907
782,751
89,156
PROJECT ECONOMICS
Based on cost information entered by the user along with calculated Participant Incentive amounts, the project economics are summarized. If the motor option is selected, the Participant
Incentive is based on the Prescriptive Motor Eligible Measures Worksheet. In this scenario, the Demand Savings and Energy Savings are backed out of the calculated Participant
Incentive and the prescriptive amount is entered.
Assumed Blended Electricity Rate ($/kWh):
$
0.110
Assumed Demand Rate ($/kW)
$
5.50
Estimated Annual Energy Savings ($/year):
$
9,807
Other Savings (Cost) ($/year):
$
-
Estimated Total Annual Savings ($/year):
$
9,807
Demand Savings1(kW) for the purpose of calculating the
Participant Incentive
19.6
Energy Savings2 (kWh) for the purpose of calculating the
Participant Incentive
89,156
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy (kWh)
Savings
Total Eligible Costs for the Project($):
$
31,965
Calculated kW Participant Incentive ($800/kW of Demand Savings)
$
15,680
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
$
8,916
$
15,680
3,4
Estimated Participant Incentive Amount :
Simple Payback (without Participant Incentive)
3.3
Simple Payback (with Participant Incentive)
1.7
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic with respect to the facility consumption.
Peak kW Savings - Percent of Facility Summer Peak Demand
9.5%
Facility Total kWh
Average kW Savings - Percent of Summer Peak Demand
0.0%
Max Summer kW
1,741,050
206
Percent of Facility Winter Peak Demand
10.0%
Max Winter kW
195
Average Savings - Percent of Winter Peak Demand
9.6%
Percent of Facility Total Annual Electricity Consumption
5.1%
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
96%
Average to Maximum Ratio exceeds Average to Maximum Threshold Level4:
YES
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5
pm on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount for this Engineering Worksheet is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant
Incentive. As indicated above, if the motor option is selected, the Participant Incentive is based on the Prescriptive Motor Eligible Measures Worksheet. In this scenario, the Demand
Savings and Energy Savings are backed out of the calculated Participant Incentive and the prescriptive amount is entered.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project
Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the
basis for the 50% Project Cost Cap.
Compressed Air Worksheet
A mark of the Province of Ontario protected under Canadian trademark law.
Outputs
Used under sublicence.
OM
Tab 11 of 11
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APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 33 of 66
RETROFIT VARIABLE SPEED DRIVE (VSD) COMPRESSED AIR WORKSHEET
A facility is installing a new VSD air compressor to replace the existing fixed speed air compressor with
intended compressor discharge pressure of 100 psig. The CAGI data sheets for the existing and new
compressors are shown below. The operating hours of the air compressor is from 7 AM to 10 PM on
weekday and 1 PM to 6 PM on weekends with 11 days of holidays annually.
Existing Fixed Speed Air Compressor is Kaeser Model # DSD 150, the efficiency performance of the
compressor is captured on a CAGI data sheet available from the manufacturer.
Proposed VSD Air Compressor is Kaeser Model # SFC 90S, the efficiency performance of the compressor
is captured on a CAGI data sheet available from the manufacturer and shown below.
On the Design and Assumption Tab, enter the intended compressor operating Discharge Pressure in
psig.
Using the fixed speed air compressor CAGI Data Sheet shown below, enter information in Box # 1, 2, 3,
4, 10 & 11. Once all information is entered, a graph is generated on the side showing power and flow
relationship of (y = mx + b) y = 0.131x + 29.7
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 34 of 66
Using the VSD Compressor CAGI Data Sheet, enter information shown in Box # 1, 2, 3, 4, 10 & 11. Once
all information is entered, a 2nd degree polynomial equation is generated (y = ax2 + bx + c) y = 1.01E-05x2
+ 0.1897x + 0.2369 and graphically shown on the side.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 35 of 66
Enter a typical operationg profile that sums up to 100%. For example as shown below, 56% of the time,
the air compressor operates between 40 to 49.9% of maximum flow.
It is MANDATORY to provide a short note describing or explaining how the flow profile was determined.
If this field is left blank, the energy savings will automatically default to 0.
Calculation of Energy and demand savings:
Refer to the following tables for the computation of the energy and demand savings:
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 36 of 66
For example at 40 to 49.9% Flow Bin Profile, demand for fixed power is y = 0.131x + 29.7 = 0.131 (218) + 29.7 =
58.26 x 56% = 32.59 kW
Demand for Variable speed power is y = 1.01E-05x2 + 0.1897x + 0.2369 = 1.01E-05 (218)2 + 0.1897x +
0.2369 = 42.03 x 56% = 23.59 kW
The sum of demand is adjusted by the pressure difference between rated pressure and actual operating pressure
expressed in psig as per following table.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 37 of 66
Version 5.0 - Retrofit Program - VSD Compressed Air Engineering Worksheet - May 12, 2014
OPERATING INFORMATION
Using the 24 hour 7 day table below, enter "1" if the equipment is scheduled to operate and "0" if the equipment is not scheduled to operate. Times during operation will illuminate purple.
These numbers are used in energy calculations therefore if the time falls within the hour (i.e. 7:30) use your best estimate to choose the appropriate time.
Sun
Mon
Tue
Wed
Thu
Fri
Sat
0:00-0:59 am
0
0
0
0
0
0
0
1:00-1:59 am
0
0
0
0
0
0
0
2:00-2:59 am
0
0
0
0
0
0
0
3:00-3:59 am
0
0
0
0
0
0
0
4:00-4:59 am
0
0
0
0
0
0
0
5:00-5:59 am
0
0
0
0
0
0
0
6:00-6:59 am
0
0
0
0
0
0
0
7:00-7:59 am
0
1
1
1
1
1
0
8:00-8:59 am
0
1
1
1
1
1
0
9:00-9:59 am
0
1
1
1
1
1
0
10:00-10:59 am
0
1
1
1
1
1
0
11:00-11:59 am
0
1
1
1
1
1
0
12:00-12:59 pm
0
1
1
1
1
1
0
1:00-1:59 pm
1
1
1
1
1
1
1
2:00-2:59 pm
1
1
1
1
1
1
1
3:00-3:59 pm
1
1
1
1
1
1
1
4:00-4:59 pm
1
1
1
1
1
1
1
5:00-5:59 pm
1
1
1
1
1
1
1
6:00-6:59 pm
0
1
1
1
1
1
0
7:00-7:59 pm
0
1
1
1
1
1
0
8:00-8:59 pm
0
1
1
1
1
1
0
9:00-9:59 pm
0
1
1
1
1
1
0
10:00-10:59 pm
0
0
0
0
0
0
0
11:00-11:59 pm
0
0
0
0
0
0
0
Hour of Day
Adjust the number of weekdays (Monday-Friday) by month that the equipment is not operating due to statutory, civic or other holidays, lieu days or scheduled shutdowns. The numbers prepopulated in the table represent the default statutory, civic or other holidays, per the table on the right.
Ontario Holidays
January
1
February
1
New Years Day
January 1
March
0
Family Day
3rd Monday in February
April
2
Good Friday
Friday before Easter Sunday
May
1
Easter Monday
Monday after Easter Sunday
June
0
Victoria Day
Monday before May 25
July
1
Canada Day
July 1
August
1
Civic Holiday
1st Monday in August
September
1
Labour Day
1st Monday in September
October
1
Thanksgiving Day
2nd Monday in October
November
0
Christmas Day
December 25
December
2
Boxing Day
December 26
TOTAL:
11
85 This is the typical weekly number of operating hours for the equipment based on the schedule above (excluding holidays)
4260 This is the annual number of operating hours for the equipment based typical weekly and holiday schedule entered
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
V 5.0
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Compressed Air Worksheet
System Schedule
Tab 5 of 5
Page 38 of 66
Version 5.0 - Retrofit Program - VSD Compressed Air Engineering Worksheet - May 12, 2014
TYPICAL OPERATING PRESSURE
100 Intended Compressor Operating Discharge Pressure (psig)
FIXED SPEED COMPRESSOR (CAGI DATA SHEET INPUTS)
Description
Value
140
Manufacturer
2
Model
3
Rated Capacity at Full Load Operating Pressure:
671
acfm
4
Full Load Operating Pressure
115
psig
10
Total Package Input Power at Zero Flow
Total Package Input Power at Rated Capacity and Full
Load Operating Pressure
29.7
kW
117.5
kW
11
Fixed Speed Compressor
Units
Kaeser
1
DSD 150
Power Demand (kW)
CAGI Data
Sheet Field #
120
100
80
60
40
20
-
-
5.7 Full Load Flow:Power ratio seems OK (4-6 acfm/kW)
200
400
Flow (acfm)
600
800
Rated Pressure of Fixed Speed Compressor seems OK for Operating Pressure Requirements.
VSD COMPRESSOR (CAGI DATA SHEET INPUTS)
Description
Data Input
1
Manufacturer
2
Model Number
3
Rated Operating Pressure (psig)
8
Input Power and Capacity
Kaeser
120
Input Power (kW)
Capacity (acfm)
Point 1 (Max)
95.5
484.0
Point 2
81.4
424.0
Point 3
55.6
293.0
Point 4
40.0
207.0
Point 5
24.7
118.0
Point 6
0.0
0.0
Point 7
0.0
0.0
0.0
0.0
Point 8
Total Package Input Power at
Zero Flow
9
VSD Compressor
SFC 90S
125
Power Demand (kW)
CAGI Data
Sheet Field #
y = 1E-05x2 + 0.1897x + 0.2369
R² = 0.9993
100
80
60
40
20
-
100
200
300
400
Flow (acfm)
500
600
Rated Pressure of VSD Compressor seems OK for Operating Pressure Requirements.
TYPICAL OPERATING PROFILE
484 Design Basis Maximum Flow (acfm)
Bin Midpoint
Flow (acfm)
Rated Flow Bin
Profile (based
on Smaller
Compressor)
Percent of
Time in This
Flow Range
0
0%
0%
24
0-9.9%
0%
73
10-19.9%
0%
121
20-29.9%
0%
169
30-39.9%
0%
218
40-49.9%
56%
266
50-59.9%
24%
315
60-69.9%
8%
363
70-79.9%
0%
411
80-89.9%
5%
460
90-99.9%
484
100%
1%
Total
100%
Expected Flow Profile
60%
Percent of Time
50%
40%
30%
20%
10%
0%
6%
Percent of Full Rated Flow
OK, Total =100%
SHORT EXPLANATION
Provide short explanation regarding method used for flow profile estimate. Note this calculator does not accept VSD Compressor flows less than 40% of fully rated capacity.
Test Case
VSD and Fixed Speed Compressors are within 10% Capacity
COMMENTS & NOTES FOR TECHNICAL REVIEWER TO BE AWARE OF
Test Case
A mark of the Province of Ontario protected under Canadian trademark law.
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OM
Official Mark of the Independent Electricity System Operator. Used under licence.
V 5.0
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Compressed Air Worksheet
System Design Assumptions
Tab 5 of 5
Page 39 of 66
ECONOMIC VALUES
Value
Units
Description
0.25
$/kWh
Blended Cost of Power based on Actual Billing Data
$
$
Show Non Electrical Annual Savings as Positive (Show Costs as a Negative Number)
PROJECT COST BREAKDOWN FOR FIXED SPEED AND VSD COMPRESSOR
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and
are limited to the following list. Please enter the Eligible Costs below as applicable.
$
44,500 Actual costs of the VSD Compressor purchased and installed
$
32,550 Actual costs of an equivalent Fixed Speed Compressor purchased and installed
$
-
Actual costs to dispose or decommission the replaced equipment
$
-
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations
$
11,950 Incremental Cost of VSD Compressor vs. Fixed Speed Compressor if Project is Implemented
$
44,500 TOTAL ELIGIBLE COSTS FOR THE PROJECT
ANNUAL SAVINGS AND ECONOMICS
Value
Description
Units
253,166
kWh
Estimated Fixed Speed Compressor Annual Energy Consumption
190,373
kWh
Estimated VSD Compressor Annual Energy Consumption if Project is Implemented
62,793
kWh
Estimated Annual Energy Savings (Permanent and Non-Permanent) if Project is Implemented
59.4
kW
Estimated Fixed Speed Compressor Peak Demand while Operating
kW
Estimated VSD Compressor Peak Demand while Operating if Project is Implemented
kW
Estimated Demand Reduction (while operating) if Project is Implemented
44.7
14.7
25%
%
% Energy Savings
$
15,698
$
Annual Electrical Savings if Project is Implemented ($)
$
15,698
$
Annual Total Savings if VSD Project is Implemented
$
44,500
$
Total Project Cost for VSD Compressor ($)
$
11,950
$
Incremental Capital Cost for Improvements if Project is Implemented ($)
$
2.8
Years
Simple Payback for Incremental Cost Before Incentive (years)
11,760
$
Years
Potential Incentive Amount ($)
Simple Payback for Incremental Cost After Incentive (years)
2.1
CONDITIONS AND DISCLAIMERS
Note 1: Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour,
service, administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by
energy ratepayers or taxpayers in the Province of Ontario (other than funding principally directed to Social Housing Providers if,
combined with the Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates from
manufacturers or wholesalers or other supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
V 5.0
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Compressed Air Worksheet
System Design Assumptions
Tab 5 of 5
Page 40 of 66
Version 5.0 - Retrofit Program - VSD Compressed Air Engineering Worksheet - May 12, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the savings associated with implementing the energy
efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
59.4
44.7
14.7
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
57.3
43.1
14.2
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
96%
96%
96%
Maximum Winter Peak Period Demand (kW)
59.4
44.7
14.7
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
56.6
42.6
14.0
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
95%
95%
95%
Annual Electricity Consumption (kWh)
253,166
190,373
62,793
PROJECT ECONOMICS
Based on cost information entered by the user along with calculated Participant Incentive amounts, the project economics are summarized. If the motor option is selected, the
Participant Incentive is based on the Prescriptive Motor Eligible Measures Worksheet. In this scenario, the Demand Savings and Energy Savings are backed out of the calculated
Participant Incentive and the prescriptive amount is entered.
Assumed Blended Electricity Rate ($/kWh):
$
0.250
Estimated Annual Energy Savings ($/year):
$
15,698
Other Savings (Cost) ($/year):
$
-
Estimated Total Annual Savings ($/year):
$
15,698
Demand Savings1(kW) for the purpose of calculating the
Participant Incentive
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy (kWh)
Savings
14.7
2
Energy Savings (kWh) for the purpose of calculating the
Participant Incentive
62,793
Total Eligible Costs for the Project($):
$
44,500
Calculated kW Participant Incentive ($800/kW of Demand Savings)
$
11,760
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
$
6,279
Estimated Participant Incentive Amount3,4:
$
11,760
Simple Payback (without Participant Incentive)
2.8
Simple Payback (with Participant Incentive)
2.1
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic with respect to the facility consumption.
Peak kW Savings - Percent of Facility Summer Peak Demand
0.0%
Facility Total kWh
-
Average kW Savings - Percent of Summer Peak Demand
0.0%
Max Summer kW
-
Percent of Facility Winter Peak Demand
0.0%
Max Winter kW
-
Average Savings - Percent of Winter Peak Demand
0.0%
Percent of Facility Total Annual Electricity Consumption
0.0%
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
96%
4
Average to Maximum Ratio exceeds Average to Maximum Threshold Level :
YES
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5
pm on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant Incentive, with a Maximum
Allowable Participant Incentive at 50% of Total Eligible Costs for the Project.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the
Project Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn,
serve as the basis for the 50% Project Cost Cap.
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of theIndependent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Compressed Air Worksheet
Outputs
Tab 5 of 5
Page 41 of 66
RETROFIT VARIABLE SPEED DRIVE (VSD) ON FANS ENGINEERED WORKSHEET
A company has decided to install a VSD on its 50,000 cfm fan. The fan’s operating hours are from 6:00
a.m. to 10:00 p.m. Mondays to Fridays and from 7:00 a.m. to 7:00 p.m. on Saturdays. The facility is
closed on Sundays and holidays. The existing fan and motor information are as follows:
FAN AND MOTOR INFORMATION
Units
Description
890
rpm
Motor Rated Speed
200
BHP
Motor Rated Power
68
°F
0.075
lb/ft3
Gas Temperature
Density of Gas (use 0.075 lb/ft3 for air at 68F)
19.5
"WG
Design Head (at X)
0.0
"WG
Static Head
ABC-123
n/a
Motor Make and Model
XYZ-999
n/a
Fan Make and Model
10
years
Approximate age of Motor
10
years
Approximate age of Fan
The design head and fan efficiency for different percent flow as read from the performance curve of the
fan, as well as the operating profile are entered on the following table:
0-10%
Design Head
("WG)
18.0
Corresponding
Fan Efficiency (%)
20
10-20%
20-30%
30-40%
40-50%
50-60%
60-70%
18.4
18.8
19.3
19.6
19.9
20.1
20
20
20
30
40
50
10
25
70-80%
80-90%
90-100%
Design
20.1
20.0
19.5
19.5
60
70
80
87
30
20
15
100
%Flow
Operating
Profile (%)
The fan curve and the operating profile as generated by the Engineered Worksheet are shown on the
next page.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 42 of 66
Fan Curve
Total Head (inches)
20.5
20.0
19.5
y = -2E-09x2 + 0.0001x + 17.499
R² = 0.9721
19.0
18.5
18.0
17.5
-
10,000
20,000
30,000
40,000
50,000
Fan Flow (CFM)
Fan Operating Profile
Operating Profile (%)
35
30
25
20
15
10
5
0-10% 10-20% 20-30% 30-40% 40-50% 50-60% 60-70% 70-80% 80-90% 90-100%
Percent Flow
FAN AND MOTOR EFFICIENCY
Units
Description
93.0
%
Motor Full Load Efficiency
86.7
%
Fan Efficiency at Damper Fully Open
0.96
fraction
Motor Efficiency Correction Factor for Lower Loads
0.95
fraction
VSD Efficiency Factor (When Operating > 40% Load)
0.82
fraction
Motor Efficiency Correction Factor for VSD Operation
0.96
fraction
Belt/Coupling Efficiency Factor
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 43 of 66
Calculation of Energy Savings (kWh):
For each % flow in the conventional fan system, the fan horsepower (FHP) is calculated using the
following equation:
Fan Horsepower (FHPb)
Qb x P x U
Kfan x 6356
=
For 50-60% flow, consider Qb = 50,000 cfm x 0.55 = 27,500 cfm; P = 19.9”WG; U = 0.075 lbs/ft3; and Kfan =
0.40
Fan Horsepower (FHPb)
=
27,500 x 19.9 x 1.0
0.40 x 6356
=
215.25 hp
The conventional fan system energy consumption (kWh) for each bin is calculated using the following
equation:
Conventional Annual Energy
Consumption (kWhb)
=
FHPb x 0.746 x H
(Kmotor x Kbelt/coupling) / 100
The annual operating hours is located under the System Schedule tab. For the above equation, H
represents the operating hours for each % flow. For 50-60%, H = 4620 hours x 0.10 = 462 hours.
Conventional Annual Energy
Consumption (kWhb)
=
=
215.25 x 0.746 x 462
(0.93 x 0.96 x 0.96) / 100
86,556 kWh
Conventional Annual Energy Consumption (kWhb) for each Flow
%Flow
Flow
(cfm)
2,500
Design Head
("WG)
18.0
Fan Efficiency
(%)
20
0-10%
10-20%
20-30%
Operating
Profile (%)
7,500
18.4
20
108.56
Hours
Fan HP
kWh
35.40
12,500
18.8
20
184.86
30-40%
17,500
19.3
20
265.69
40-50%
22,500
19.6
30
231.28
50-60%
27,500
19.9
40
10
462
215.25
86,556
50
25
60-70%
32,500
20.1
1,155
205.55
206,643
70-80%
37,500
20.1
60
30
1,386
197.65
231,209
80-90%
42,500
20.0
70
20
924
191.05
148,990
90-100%
47,500
693
182.16
106,546
Total:
779,945
Design
19.5
80
15
19.5
87
100
The total annual energy consumption for the base case sums up all the energy consumption in the 10
bins. For this particular example, total annual energy consumption is 779,945 kWh.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 44 of 66
Likewise, for the Variable Speed Drive on Fans option, the annual energy consumption in kWh is
calculated the same way as the Conventional Fan System except that there is an additional definition for
total head and efficiencies.
P
=
Ps + (Pd – Ps) ( Q / Qd )
2
For the 50-60% flow, static head Ps = 0; design head for Pd = 19.5 in H2O; Q = 27,500 cfm; Qd = 50,000
cfm
P
=
0 + (19.5 – 0) ( 27,500 / 50,000 )
P
=
5.90 in H2O
2
Calculate the fan horsepower for the VSD option:
Fan Horsepower (FHPr)
Qr x P x U
Kfan x 6356
=
For 50-60% flow, consider Qr = 50,000 cfm x 0.55 = 27,500 cfm; P = 5.9”WG; U = 0.075 lbs/ft3; and Kfan =
0.867
Fan Horsepower (FHPr)
=
27,500 x 5.9 x 1.0
0.867 x 6356
=
29.44 hp
The energy consumption (kWh) for each bin for the VSD option is calculated using the following
equation:
VSD Option Annual Energy
Consumption (kWhr)
FHPr x 0.746 x H
=
Kmotor x KVSD x Kbelt/coupling
29.44 x 0.746 x 462
=
(0.93 x 0.82) x 0.95 x 0.96
= 14,587 kWh
The total annual energy consumption for the VSD option sums up all the energy consumption in the 10
bins. For this particular example, total annual energy consumption is 406,201 kWh. See table on the
next page.
Getting the difference between the conventional and the VSD option, annual savings is calculated to be
373,743 kWh.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 45 of 66
VSD Option Annual Energy Consumption (kWhb) for each Flow
%Flow
Flow
(cfm)
System
Head
0.05
0.44
1.22
2.39
3.95
5.90
0-10%
2,500
10-20%
7,500
20-30%
12,500
30-40%
17,500
40-50%
22,500
50-60%
27,500
60-70%
32,500
70-80%
37,500
80-90%
8.24
10.97
14.09
17.60
42,500
90-100%
Operating
Profile (%)
47,500
Design
Hours
Fan HP
kWh
10
462
0.02
0.60
2.76
7.59
16.12
29.44
14,587
71,969
25
1,155
30
1,386
20
924
15
693
48.59
74.64
108.66
151.70
Total:
60,196
110,968
107,691
112,759
406,201
146,447
120,242
41,300
(6,213)
373,743
100
Savings
Calculation of Demand Savings (kW):
The maximum summer and winter peak period demand (kW) savings are calculated by dividing the
annual energy savings (kWh) by the total annual hours of operation.
Demand Savings (kW)
Annual Energy Savings (kWh)
Annual Operating Hours (hrs)
=
= 373,743 kWh /4620 hrs
= 80.9 kW
Calculation of Total Project Costs ($):
It is assumed that the total project costs amount to $ 141,500.00 broken down as follows:
Variable speed drive cost
Labour to install VSD
$ 125,000.00
$ 16,500.00
Total:
$ 141,500.00
Calculation of Incentives ($):
Calculated kW Participant Incentive ($800/kW of Demand Savings):
Participant Incentive
=
80.9 kW
x
=
$ 64,720.00
$800/kW
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 46 of 66
Calculated kWh Participant Incentive ($0.10/kW of Energy Savings)
Participant Incentive
=
373,743 kWh
=
$ 37,374.00
x
$ 0.10/kWh
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 47 of 66
Version 5.0 - Retrofit Program- Variable Speed Drive on Fan Engineering Worksheet - December 5, 2014
OPERATING INFORMATION
Using the 24 hour 7 day table below, enter "1" if the equipment is scheduled to operate and "0" if the equipment is not scheduled to operate. Times during operation will illuminate green.
These numbers are used in energy calculations, therefore if the time falls within the hour (i.e. 7:30), use your best estimate to choose the appropriate time.
Hour of Day
Sun
Mon
Tue
Wed
Thu
Fri
Sat
0:00-0:59 am
0
0
0
0
0
0
0
1:00-1:59 am
0
0
0
0
0
0
0
2:00-2:59 am
0
0
0
0
0
0
0
3:00-3:59 am
0
0
0
0
0
0
0
4:00-4:59 am
0
0
0
0
0
0
0
5:00-5:59 am
0
0
0
0
0
0
0
6:00-6:59 am
0
1
1
1
1
1
0
7:00-7:59 am
0
1
1
1
1
1
1
8:00-8:59 am
0
1
1
1
1
1
1
9:00-9:59 am
0
1
1
1
1
1
1
10:00-10:59 am
0
1
1
1
1
1
1
11:00-11:59 am
0
1
1
1
1
1
1
12:00-12:59 pm
0
1
1
1
1
1
1
1:00-1:59 pm
0
1
1
1
1
1
1
2:00-2:59 pm
0
1
1
1
1
1
1
3:00-3:59 pm
0
1
1
1
1
1
1
4:00-4:59 pm
0
1
1
1
1
1
1
5:00-5:59 pm
0
1
1
1
1
1
1
6:00-6:59 pm
0
1
1
1
1
1
1
7:00-7:59 pm
0
1
1
1
1
1
0
8:00-8:59 pm
0
1
1
1
1
1
0
9:00-9:59 pm
0
1
1
1
1
1
0
10:00-10:59 pm
0
0
0
0
0
0
0
11:00-11:59 pm
0
0
0
0
0
0
0
Adjust the number of weekdays (Mon-Fri) by month that the equipment is not operating due to statutory holidays, lieu days or scheduled shutdowns. The numbers pre-populated in the
table represent the default statutory holidays, per the table on the right.
Ontario Statutory Holidays
January
1
February
1
New Years Day
January 1
March
0
Family Day
3rd Monday in February
April
2
Good Friday
Friday before Easter Sunday
May
1
Easter Monday
Monday after Easter Sunday
June
0
Victoria Day
Monday before May 25
July
1
Canada Day
July 1
August
1
Civic Holiday
1st Monday in August
September
1
Labour Day
1st Monday in September
October
1
Thanksgiving Day
2nd Monday in October
November
0
Christmas Day
December 25
December
2
Boxing Day
December 26
TOTAL:
11
92 This is the typical weekly number of operating hours for the equipment based on the schedule above (excluding holidays)
4620 This is the annual number of operating hours for the equipment based typical weekly and holiday schedule entered
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Fan System VSD Worksheet
System Schedule
Tab 3 of 5
Page 48 of 66
Version 5.0 - Retrofit Program- Variable Speed Drive on Fan Engineering Worksheet - December 5, 2014
FAN CURVE AND OPERATING PROFILE
50,000 Enter the Fan Design Flow in Cubic Feet per Minute
Using the table below, enter fan curve data (head and efficiency), and fan flow duration.
Tip: Keep an eye on the graphs to the right to aid with visualizing the fan characteristics.
0-10%
18.0
20
10-20%
18.4
20
20-30%
18.8
20
30-40%
19.3
20
40-50%
19.6
30
50-60%
19.9
40
Operating
Profile (%)
Fan Curve
20.5
20.0
10
Total Head (inches)
Corresponding
Fan Efficiency
(%)
Design Head
("WG)
%Flow
19.5
y = -2E-09x2 + 0.0001x + 17.499
R² = 0.9721
19.0
18.5
60-70%
20.1
50
25
18.0
70-80%
20.1
60
30
17.5
80-90%
20.0
70
20
90-100%
19.5
80
15
Design
19.5
87
100
-
10,000
20,000
30,000
50,000
40,000
Fan Flow (CFM)
OK
FAN AND MOTOR INFORMATION
Fan Operating Profile
This information can typically be found on the motor and fan specification sheets, or can
35
be obtained by contacting the manufacturer(s)
rpm
Motor Rated Speed
200
BHP
Motor Rated Power
68
°F
0.075
lb/ft3
Gas Temperature
Density of Gas (use 0.075 lb/ft3 for air at 68F)
19.5
"WG
Design Head (at X)
0.0
"WG
Static Head
ABC-123
n/a
Motor Make and Model
XYZ-999
n/a
Fan Make and Model
10
years
Approximate age of Motor
10
years
Approximate age of Fan
30
Operating Profile (%)
Description
Units
890
25
20
15
10
5
0-10%
10-20%
20-30%
30-40%
40-50%
50-60%
60-70%
70-80%
80-90% 90-100%
Percent Flow
FAN AND MOTOR EFFICIENCY
86.7
%
Motor Full Load Efficiency
%
Fan Efficiency at Damper Fully Open
0.96
fraction
Motor Efficiency Correction Factor for Lower Loads
0.95
fraction
VSD Efficiency Factor (When Operating > 40% Load)
0.82
fraction
Motor Efficiency Correction Factor for VSD Operation
0.96
fraction
Belt/Coupling Efficiency Factor
ECONOMIC VALUES
Description
Units
$
0.1100
$
6.00
$
-
$/kWh
Blended Cost of Power
$/kW
Estimated Monthly Peak Demand Unit Cost
$
Non Electrical Annual Savings (Cost is -ve)
Annual Energy Consumption (kWh)
93.0
Conventional & VSD Energy by Operating Point
Description
Units
250,000
200,000
150,000
100,000
50,000
1
2
3
4
5
6
7
8
9
10
Operating Point
Conventional
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Case
Fan System VSD Worksheet
System Design Assumptions
Tab 4 of 5
Page 49 of 66
PROJECT COST BREAKDOWN
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and are
limited to the following list. Please enter the Eligible Costs as applicable
$
$
125,000 Actual costs of the equipment purchased and installed
16,500 Actual costs of labour for the installation of the equipment by suppliers
Actual costs of dispose of or decommission the replaced equipment
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations
$
141,500 TOTAL ELIGIBLE COSTS FOR THE PROJECT
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour, service, administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by energy ratepayers or taxpayers in the Province of Ontario
(other than funding principally directed to Social Housing Providers if, combined with the Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates
from manufacturers or wholesalers or other supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Fan System VSD Worksheet
System Design Assumptions
Tab 4 of 5
Page 50 of 66
Version 5.0 - Retrofit Program- Variable Speed Drive on Fan Engineering Worksheet - December 5, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the Energy Savings and Demand Savings associated with
implementing the energy efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
168.8
87.9
80.9
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
162.9
84.8
78.0
(Summer On-Peak Energy/On-Peak Hours)
1.0
1.0
1.0
Average to Maximum Ratio (%)
Maximum Winter Peak Period Demand (kW)
168.8
87.9
80.9
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
160.8
83.7
77.0
(Winter On-Peak Energy/On-Peak Hours)
1.0
1.0
1.0
779,945
406,201
373,743
Average to Maximum Ratio (%)
Annual Electricity Consumption (kWh)
PROJECT ECONOMICS
Based on cost information, entered by the user, along with calculated Participant Incentive amounts, the project economics are summarized.
Assumed Blended Electricity Rate ($/kWh):
$
0.110
Assumed Demand Rate ($/kW)
$
6.00
Estimated Annual Energy Savings ($/year):
$
41,112
Other Savings (Cost) ($/year):
$
-
Estimated Total Annual Savings ($/year):
$
41,112
Demand Savings1(kW) for the purpose of calculating the
Participant Incentive
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy
(kWh) Savings
80.9
2
Energy Savings (kWh) for the purpose of calculating the
Participant Incentive
373,743
Total Eligible Costs for the Project($):
$
141,500
Calculated kW Participant Incentive ($800/kW of Demand Savings)
$
64,720
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
$
37,374
Estimated Participant Incentive Amount3,4:
$
64,720
Simple Payback (without Participant Incentive)
$
3
Simple Payback (with Participant Incentive)
$
2
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the calculated Energy Savings and Demand Savings are realistic, with respect to the facility consumption.
Peak kW Savings - Percent of Facility Summer Peak Demand
12.3%
Facility Total kWh
37,188,244
Average kW Savings - Percent of Summer Peak Demand
11.8%
Max Summer kW
660
Percent of Facility Winter Peak Demand
12.4%
Max Winter kW
650
Average Savings - Percent of Winter Peak Demand
11.9%
Percent of Facility Total Annual Electricity Consumption
1.0%
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
96%
Average to Maximum Ratio exceeds Average to Maximum Threshold Level:
YES
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5 pm
on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount for this Engineering Worksheet is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant
Incentive.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project
Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the
basis for the 50% Project Cost Cap.
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Fan System VSD Worksheet
Outputs
Tab 5 of 5
Page 51 of 66
RETROFIT Variable Speed Drive (VSD) on Pump Engineered Worksheet
A company has decided to install a VSD on its 1,100 gpm pump. The fan’s operating hours are from
10:00 a.m. to 8:00 p.m. Mondays to Fridays and from 10:00 a.m. to 5:00 p.m. on Saturdays. The facility
is closed on Sundays and holidays. The existing pump and motor information are as follows:
FAN AND MOTOR INFORMATION
Units
Description
1750
rpm
Motor Rated Speed
75
BHP
Motor Rated Power
Fluid Temperature
65
°F
1.00
S.G.
190.0
ft
Design Head (at X)
Static Head
Specific Gravity of Fluid (Water =1.00)
20.0
ft
ABC-123
n/a
Motor Make & Model
XYZ-999
n/a
Pump Make and Model
5
years
Approximate age of Motor
3
years
Approximate Age of Pump
The pump head and pump efficiency for different percent flow as read from the performance curve of
the pump, as well as the operating profile are entered on the following table:
%Flow
0-10%
10-20%
20-30%
30-40%
40-50%
50-60%
60-70%
70-80%
80-90%
90-100%
Design
235.0
230.0
Corresponding
Pump Efficiency
(%)
20.0
20.0
223.0
223.0
220.0
215.0
210.0
207.0
35.0
50.0
60.0
70.0
72.0
74.0
5.0
10.0
20.0
25.0
203.0
195.0
190
76.0
78.0
80
25.0
15.0
100
Pump Head
(ft)
Operating
Profile (%)
The pump curve and the operating profile as generated by the Engineered Worksheet are shown on the
next page.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 52 of 66
Pump Curve (Points from Manufacturer)
250.0
Pump Head (feet)
200.0
150.0
y = -7E-06x2 - 0.0292x + 235.03
R² = 0.984
100.0
50.0
-
200
400
600
800
1,000
1,200
Pump Flow (USGPM)
Flow Duration Profile
Operating Profile (%)
30
25
20
15
10
5
0-10%
20-30%
40-50%
60-70%
80-90%
Percent Flow
PUMP AND MOTOR EFFICIENCY
Units
Description
95.4
%
Motor Full Load Efficiency
80.0
%
Pump Efficiency (at X)
0.95
fraction
Motor Efficiency Correction Factor for Lower Loads
0.95
fraction
VSD Efficiency Factor (When Operating > 40% Load)
0.82
fraction
Motor Efficiency Correction Factor for VSD Operation
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 53 of 66
Calculation of Energy Savings (kWh):
For each % flow in the conventional pump system, the pump horsepower (PHP) is calculated using the
following equation:
Pump Horsepower (PHPb)
Qb x P x J
Kpump x 3958
=
For 50-60% flow, consider Qb = 1,100 gpm x 0.55 = 605 gpm; P = 215 ft; J = 1.0; and Kpump = 0.70
Pump Horsepower (PHPb)
=
605 x 215 x 1.0
0.70 x 3958
=
46.95 hp
The conventional pump system energy consumption (kWh) for each bin is calculated using the following
equation:
Conventional Annual Energy
Consumption (kWhb)
PHPb x 0.746 x H
(Kmotor)
=
The annual operating hours is located under the System Schedule tab. For the above equation, H
represents the operating hours for each % flow. For 50-60%, H = 2861 hours x 0.10 = 286 hours.
Conventional Annual Energy
Consumption (kWhb)
=
=
46.95 x 0.746 x 286.1
(0.954 x 0.95)
11,056.6 kWh
Conventional Annual Energy Consumption (kWhb) for each Flow
%Flow
Flow
(GPM)
Design Head
(ft)
Pump Efficiency
(%)
0-10%
55
235.0
10-20%
165
20-30%
30-40%
40-50%
Pump
HP
kWh
20.0
16.33
-
230.0
20.0
47.94
-
275
223.0
35.0
44.27
-
385
223.0
50.0
43.38
-
495
220.0
60.0
5.0
143
45.86
5,699
50-60%
605
215.0
70.0
10.0
286
46.95
11,056
60-70%
715
210.0
72.0
20.0
572
52.69
24,816
70-80%
825
207.0
74.0
25.0
715
58.31
32,940
80-90%
935
203.0
76.0
25.0
715
63.10
35,648
90-100%
1,045
195.0
78.0
15.0
429
190
80
100
Design
Operating
Profile (%)
Hours
66.01
22,374
Total:
132,534
The total annual energy consumption for the base case sums up all the energy consumption in the 10
bins. For this particular example, total annual energy consumption is 132,534 kWh.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 54 of 66
Likewise, for the Variable Speed Drive on Pump option, the annual energy consumption in kWh is
calculated the same way as the Conventional Pump System except that there is an additional definition
for total head and efficiencies.
P
=
Ps + (Pd – Ps) ( Q / Qd )
2
For the 50-60% flow, static head Ps = 20 ft; design head for Pd = 190 ft; Q = 605 gpm; Qd = 1100 gpm
P
=
20 + (190 – 20) ( 605 / 1100 )
P
=
71.43 ft
2
Calculate the fan horsepower for the VSD option:
Pump Horsepower (PHPr)
Qr x P x J
Kpump x 3958
=
For 50-60% flow, consider Qr = 1,100 gpm x 0.55 = 605 gpm; P = 71.43 ft; J = 1.0; and Kpump = 0.80
Pump Horsepower (PHPr)
=
605 x 71.43 x 1.0
0.8 x 3958
= 13.65 hp
The energy consumption (kWh) for each bin for the VSD option is calculated using the following
equation:
VSD Option Annual Energy
Consumption (kWhr)
PHPr x 0.746 x H
=
Kmotor x KVSD
13.65 x 0.746 x 286
=
(0.954 x 0.82) x 0.95
= 3,919 kWh
The total annual energy consumption for the VSD option sums up all the energy consumption in the 10
bins. For this particular example, total annual energy consumption is 93,617 kWh. See table on the next
page.
Getting the difference between the conventional and the VSD option, annual savings is calculated to be
38,917 kWh.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 55 of 66
VSD Option Annual Energy Consumption (kWhb) for each Flow
%Flow
Flow
(gpm)
System
Head
Operating
Profile (%)
Hours
Pump
HP
kWh
Savings
0-10%
55
20.43
0.35
-
-
10-20%
165
23.83
1.24
-
-
20-30%
275
30.63
2.66
-
-
30-40%
385
40.83
4.96
-
-
40-50%
495
54.43
5.0
143
8.51
1,222
4,478
50-60%
605
71.43
10.0
286
13.65
3,919
7,137
60-70%
715
91.83
20.0
572
20.73
11,910
12,906
70-80%
825
115.63
25.0
715
30.13
21,630
11,311
80-90%
935
142.83
25.0
715
42.17
30,280
5,367
90-100%
1,045
173.43
15.0
429
Design
100
57.24
24,656
(2,282)
Total:
93,617
38,917
Calculation of Demand Savings (kW):
The maximum summer and winter peak period demand (kW) savings are calculated by dividing the
annual energy savings (kWh) by the total annual hours of operation.
Demand Savings (kW)
Annual Energy Savings (kWh)
Annual Operating Hours (hrs)
=
= 38,917 /2861 hrs
= 13.6 kW
Calculation of Total Project Costs ($):
It is assumed that the total project costs amount to $ 30,800.00 broken down as follows:
Variable speed drive cost
Labour to install VSD
$ 23,200.00
$ 7,600.00
Total:
$ 30,800.00
Calculation of Incentives ($):
Calculated kW Participant Incentive ($800/kW of Demand Savings):
Participant Incentive
=
13.6 kW
x
=
$ 10,880.00
$800/kW
Calculated kWh Participant Incentive ($0.10/kW of Energy Savings)
Participant Incentive
=
38,917 kWh
=
$ 3,892.00
x
$ 0.10/kWh
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 56 of 66
Version 5.0 - Retrofit Program - Variable Speed Drive on Pump Engineering Worksheet - December 5, 2014
OPERATING INFORMATION
Using the 24 hour 7 day table below, enter "1" if the equipment is scheduled to operate and "0" if the equipment is not scheduled to operate. Times during operation will illuminate purple.
These numbers are used in energy calculations, therefore if the time falls within the hour (i.e. 7:30), use your best estimate to choose the appropriate time.
Sun
Mon
Tue
Wed
Thu
Fri
Sat
0:00-0:59 am
0
0
0
0
0
0
0
1:00-1:59 am
0
0
0
0
0
0
0
2:00-2:59 am
0
0
0
0
0
0
0
3:00-3:59 am
0
0
0
0
0
0
0
4:00-4:59 am
0
0
0
0
0
0
0
5:00-5:59 am
0
0
0
0
0
0
0
6:00-6:59 am
0
0
0
0
0
0
0
7:00-7:59 am
0
0
0
0
0
0
0
8:00-8:59 am
0
0
0
0
0
0
0
9:00-9:59 am
0
0
0
0
0
0
0
10:00-10:59 am
0
1
1
1
1
1
1
11:00-11:59 am
0
1
1
1
1
1
1
12:00-12:59 pm
0
1
1
1
1
1
1
1:00-1:59 pm
0
1
1
1
1
1
1
2:00-2:59 pm
0
1
1
1
1
1
1
3:00-3:59 pm
0
1
1
1
1
1
1
4:00-4:59 pm
0
1
1
1
1
1
1
5:00-5:59 pm
0
1
1
1
1
1
0
6:00-6:59 pm
0
1
1
1
1
1
0
7:00-7:59 pm
0
1
1
1
1
1
0
8:00-8:59 pm
0
0
0
0
0
0
0
9:00-9:59 pm
0
0
0
0
0
0
0
10:00-10:59 pm
0
0
0
0
0
0
0
11:00-11:59 pm
0
0
0
0
0
0
0
Hour of Day
Adjust the number of weekdays (Mon-Fri) by month that the equipment is not operating due to statutory holidays, lieu days or scheduled shutdowns. The numbers pre-populated in the
table represent the default statutory holidays, per the table on the right.
Ontario Statutory Holidays
January
1
February
1
New Years Day
January 1
March
0
Family Day
3rd Monday in February
April
2
Good Friday
Friday before Easter Sunday
May
1
Easter Monday
Monday after Easter Sunday
June
0
Victoria Day
Monday before May 25
July
1
Canada Day
July 1
August
1
Civic Holiday
1st Monday in August
September
1
Labour Day
1st Monday in September
October
1
Thanksgiving Day
2nd Monday in October
November
0
Christmas Day
December 25
December
2
Boxing Day
December 26
TOTAL:
11
57 This is the typical weekly number of operating hours for the equipment based on the schedule above (excluding holidays)
2861 This is the annual number of operating hours for the equipment based typical weekly and holiday schedule entered
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Pump System VSD Worksheet
System Schedule
Tab 3 of 5
Page 57 of 66
Version 5.0 - Retrofit Program - Variable Speed Drive on Pump Engineering Worksheet - December 5, 2014
PUMP CURVE AND OPERATING PROFILE
1,100 Enter Pump Design Flow in US Gallons per Minute
Using the table below, enter pump curve data (head and efficiency), and pump flow duration.
Tip: Keep an eye on the graphs to the right to aid with visualizing the pump characteristics.
%Flow
Pump Head
(ft)
Corresponding
Pump Efficiency
(%)
20.0
230.0
20.0
20-30%
223.0
35.0
30-40%
223.0
50.0
40-50%
220.0
60.0
5.0
50-60%
215.0
70.0
10.0
60-70%
210.0
72.0
20.0
70-80%
207.0
74.0
25.0
80-90%
203.0
76.0
25.0
195.0
190.0
78.0
Pump Head (feet)
235.0
90-100%
250.0
200.0
0-10%
10-20%
Design
Pump Curve (Points from Manufacturer)
Operating
Profile (%)
150.0
y = -7E-06x2 - 0.0292x + 235.03
R² = 0.984
100.0
50.0
-
200
400
15.0
80
600
800
1,000
1,200
Pump Flow (USGPM)
100
Operating Profile sum equals 100%:
YES
PUMP AND MOTOR INFORMATION
Flow Duration Profile
This information can typically be found on the motor and pump specification sheets, or
30
Description
Units
1750
rpm
Motor Rated Speed
75
BHP
Motor Rated Power
65
°F
1.00
S.G.
190.0
ft
Design Head (at X)
ft
Static Head
20.0
Fluid Temperature
Specific Gravity of Fluid (Water =1.00)
Operating Profile (%)
can be obtained by contacting the manufacturer(s)
25
20
15
10
5
ABC-123
alphanumeric Motor Make & Model
XYZ-999
alphanumeric Pump Make and Model
-
5
years
Approximate age of Motor
3
years
Approximate Age of Pump
0-10%
Percent Flow
PUMP AND MOTOR EFFICIENCY
%
Motor Full Load Efficiency
80.0
%
Pump Efficiency (at X)
0.95
fraction
Motor Efficiency Correction Factor for Lower Loads
0.95
fraction
VSD Efficiency Factor (When Operating > 40% Load)
0.82
fraction
Motor Efficiency Correction Factor for VSD Operation
ECONOMIC VALUES
Description
Units
$
0.11
$/kWh
Blended Cost of Power
$
5.50
$/kW
Estimated Monthly Peak Demand Unit Cost
40,000
Annual Energy Consumption (kWh)
95.4
$
Conventional & VSD Energy by Operating Point
Description
Units
10-20% 20-30% 30-40% 40-50% 50-60% 60-70% 70-80% 80-90% 90-100%
35,000
30,000
25,000
20,000
15,000
10,000
5,000
1
2
3
4
5
6
7
8
9
10
Operating Point
Non Electrical Annual Savings (Cost is negative)
Conventional
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
VSD Case
Pump System VSD Worksheet
System Design Assumptions
Tab 4 of 5
Page 58 of 66
PROJECT COST BREAKDOWN
Costs which are eligible to be included in determining applicable Participant Incentives must be directly related to the procurement and implementation of the Eligible Measures and are
limited to the following list. Please enter the Eligible Costs as applicable.
$
$
23,200 Actual costs of the equipment purchased and installed
7,600 Actual costs of labour for the installation of the equipment by suppliers
Actual costs of dispose of or decommission the replaced equipment
Actual costs of inspection of the Project as may be required pursuant to Laws and Regulations
$
30,800 TOTAL ELIGIBLE COSTS FOR THE PROJECT
For certainty, costs which are not eligible to be included in Eligible Costs include:
(i) any costs that are not third party costs or that are internal costs of the Participant, including costs of the Participant’s labour, service, administration or overhead;
(ii) financing costs of the Participant;
(iii) related insurance costs of the Participant;
(iv) costs associated with post-installation maintenance or service contracts;
(v) costs of spare parts, spare equipment or other inventories;
(vi) purchase or lease of tools for installation of equipment;
(vii) HST; and
(viii) a portion of the costs of Eligible Measures that have been or will be received from financial incentives generally funded by energy ratepayers or taxpayers in the Province of Ontario
(other than funding principally directed to Social Housing Providers if, combined with the Participant Incentive, such funding does not exceed the actual cost of the Project) or rebates
from manufacturers or wholesalers or other supply chain participants.
Note: Capitalized terms above are as defined in the Participant Agreement
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Pump System VSD Worksheet
System Design Assumptions
Tab 4 of 5
Page 59 of 66
Version 5.0 - Retrofit Program - Variable Speed Drive on Pump Engineering Worksheet - December 5, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the Energy Savings and Demand Savings associated with
implementing the energy efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
46.3
32.7
13.6
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
44.7
31.6
13.1
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
96%
96%
96%
Maximum Winter Peak Period Demand (kW)
46.3
32.7
13.6
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
25.2
17.8
7.4
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
54%
54%
54%
132,534
93,617
38,917
Annual Electricity Consumption (kWh)
PROJECT ECONOMICS
Based on cost information entered by the user along with calculated Participant Incentive amounts, the project economics are summarized below.
Assumed Blended Electricity Rate ($/kWh):
$
0.110
Assumed Demand Rate ($/kW)
$
5.50
Estimated Annual Energy Savings ($/year):
$
4,281
Other Savings (Cost) ($/year):
$
-
Estimated Total Annual Savings ($/year):
$
4,281
Demand Savings1(kW) for the purpose of calculating the
Participant Incentive
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy (kWh)
Savings
13.6
2
Energy Savings (kWh) for the purpose of calculating the
Participant Incentive
38,917
Total Eligible Costs for the Project($):
$
30,800
Calculated kW Participant Incentive ($800/kW of Demand Savings)
$
10,880
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
$
3,892
Estimated Participant Incentive Amount3,4:
$
10,880
Simple Payback (without Participant Incentive)
7.2
Simple Payback (with Participant Incentive)
4.7
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic, with respect to the facility consumption.
Peak kW Savings - Percent of Facility Summer Peak Demand
0.0%
Facility Total kWh
Average kW Savings - Percent of Summer Peak Demand
0.0%
Max Summer kW
-
Percent of Facility Winter Peak Demand
0.0%
Max Winter kW
-
Average Savings - Percent of Winter Peak Demand
0.0%
Percent of Facility Total Annual Electricity Consumption
0.0%
LDC Average to Maximum Threshold Level (%)
50%
Actual Average to Maximum Threshold Level (%)
96%
Average to Maximum Ratio exceeds Average to Maximum Threshold Level:
YES
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5 pm
on business days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount for this Engineering Worksheet is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant
Incentive.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project
Cost in this Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the
basis for the 50% Project Cost Cap.
Pump System VSD Worksheet
A mark of the Province of Ontario protected under Canadian trademark law.
Outputs
Used under sublicence.
OM
Tab 5 of 5
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 60 of 66
RETROFIT UNITARY AIR-CONDITIONING (A/C) ENGINEERED WORKSHEET
A community centre in Ottawa is installing an energy efficient rooftop unit to retrofit its existing unit
serving 400 m2 of space. The facility operates from 10:00 am to 9:00 p.m. Monday to Friday and from
10:00 a.m. to 5:00 p.m. on Saturday, Sunday and holidays.
Existing Unitary A/C System (Quantity of 2):
x
x
Capacity – 72,000 Btu/h
EER – 8.9
Proposed Unitary A/C System (Quantity of 2):
x
x
Capacity – 72,000 Btu/h
EER – 12.0
Calculation of Demand Savings (kW):
The energy performance of the Unitary A/C is determined by calculating the energy consumption of
both the existing (base case) and retrofit (design case) units for each hour that the equipment operates
during the year. First, peak (rated) power (in watts) is calculated by dividing the capacity (Btu/hr) by
the energy efficiency ratio (EER). This is then converted to kilowatts.
Rated kWb
=
Capacity (Btu/h)
EER (Btu/Wh) x 1000
= 72,000 / (8.9 x 1000)
= 8.09 kW
Rated kWr
=
Capacity (Btu/h)
EER (Btu/Wh) x 1000
= 72,000 / (12.0 x 1000)
= 6.0 kW
Power consumption at part load is calculated via a methodology published by NRCan for use in a
building modeling software called EE4. This methodology is based on percentage unit output, wet bulb
and dry bulb temperatures and yields the % of peak power consumed at part load. This calculation is
performed for each hour of the year that operation is scheduled.
For this example, a community centre is selected and will assume a part load for the whole 8760 hours
represented by the graph below. For calculation purposes, we will show how power consumption at
part load is estimated using NRCan’s methodology. We will assume a weekday in July from 11:00 a.m.
to 5:00 p.m.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 61 of 66
Unit Output
1
177
353
529
705
881
1057
1233
1409
1585
1761
1937
2113
2289
2465
2641
2817
2993
3169
3345
3521
3697
3873
4049
4225
4401
4577
4753
4929
5105
5281
5457
5633
5809
5985
6161
6337
6513
6689
6865
7041
7217
7393
7569
7745
7921
8097
8273
8449
8625
Hour
Data Input Requirements
Time
11:00 am – 12:00 pm
12:00 pm – 1:00 pm
1:00 pm – 2:00 pm
2:00 pm – 3:00 pm
3:00 pm – 4:00 pm
4:00 pm – 5:00 pm
% Unit
Output
0.01250
0.03075
0.04600
0.13325
0.05625
0.13950
Dry Bulb
Temperature
73.22
73.76
75.20
74.84
75.74
75.74
Wet Bulb
Temperature
59.62
58.90
58.96
57.98
58.99
57.73
For each hour, the base consumption and retrofit consumptions will be calculated using NRCan’s
methodology.
Cooling Capacity Adjustment Curve
= 0.8740302 + (-0.0011416 x twb) + (0.0001711 x twb2) + (-0.0029570 x todb)
+ (0.0000102 x todb2) + (-0.0000592 x twb x todb)
CAP_FT
Adjustment to Rated Efficiency due to Environmental Variables
= -1.0639310 + (0.0306584 x twb) + (-0.0001269 x twb2) + (0.0154213 x todb)
+ (0.0000497 x todb2) + (-0.0002096 x twb x todb)
EIR_FT
Part Load Ratio
PLR
=
Qoperating
Qavailable (twb, todb)
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 62 of 66
Qoperating
= % Unit Output x Capacity
Qavailable (twb, todb)
=
CAP_FT x Qrated
Adjustment to Rated Efficiency due to Changes in Coil Load
= 0.2012301 + (-0.0312175 x PLR) + (1.9504979 x PLR2) + (-1.1205105 x PLR3)
EIR_FPLR
Calculated Values
Time
11:00 am – 12:00 pm
12:00 pm – 1:00 pm
1:00 pm – 2:00 pm
2:00 pm – 3:00 pm
3:00 pm – 4:00 pm
4:00 pm – 5:00 pm
CAP_FT
EIR_FT
PLRb
PLRr
EIR_FPLRb
EIR_FPLRr
0.9939
0.9806
0.9743
0.9620
0.9721
0.9541
0.7935
0.7989
0.8140
0.8100
0.8197
0.8197
0.0126
0.0314
0.0472
0.1385
0.0579
0.1462
0.0126
0.0314
0.0472
0.1385
0.0579
0.1462
0.2011
0.2021
0.2040
0.2314
0.2057
0.2349
0.2011
0.2021
0.2040
0.2314
0.2057
0.2349
To compute for the base and retrofit demand (kW) for each hour, we use
Demand (kW)b
= Rated kWb x CAP_FT x EIR_FT x EIR_FPLRb
Demand (kW)r
= Rated kWr x CAP_FT x EIR_FT x EIR_FPLRr
Time
Base Case
kW
Efficiency
Case kW
Savings
11:00 am – 12:00 pm
12:00 pm – 1:00 pm
1:00 pm – 2:00 pm
2:00 pm – 3:00 pm
3:00 pm – 4:00 pm
4:00 pm – 5:00 pm
1.2833
1.2810
1.3088
1.4584
1.3262
1.4859
0.9518
0.9501
0.9707
1.0817
0.9836
1.1020
0.3315
0.3309
0.3381
0.3768
0.3426
0.3839
Demand (kW) savings is automatically obtained by the engineered worksheet by getting the difference
of the maximum kW occurring during the summer peak window (11:00 a.m. to 5:00 pm), Mondays to
Fridays from June 01 to September 30 for both the base and retrofit case.
Max
Demand
(kW)b
= Existing AC Unit Type 1 x Quantity Type 1 + Existing AC Unit Type 2 x Quantity Type 2
+ Existing AC Unit Type 3 x Quantity Type 3
= 6.7026 kW x 2 + 0 kW x 0 + 0 kW x 0
= 13.4 kW
Max
Demand
(kW)r
= Retrofit AC Unit Type 1 x Quantity Type 1 + Retrofit AC Unit Type 2 x Quantity Type 2
+ Retrofit AC Unit Type 3 x Quantity Type 3
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 63 of 66
= 4.9710 kW x 2 + 0 kW x 0 + 0 kW x 0
= 9.9 kW
For this particular example, base case maximum demand is 13.4 kW while the retrofit case maximum
demand is 9.9 kW. Getting their difference, the demand (kW) savings is 3.5 kW (13.4 kW – 9.9 kW).
Calculation of Energy Savings (kWh):
The base case and retrofit case energy consumption (kWh) are obtained by summing up all the demand
(kW) for each hour for the whole 8760 hours. Base case energy consumption is 6,051 kWh while the
retrofit case energy consumption is 4,488 kWh. Energy savings, therefore, is 1,563 kWh (6,051 kWh 4,488 kWh)
Calculation of Total Project Costs ($):
It is assumed that the total project costs amount to $ 12,000.00 broken down as follows:
Variable speed drive cost
Labour to install VSD
$ 10,000.00
$ 2,000.00
Total:
$ 12,000.00
Calculation of Incentives ($):
Calculated kW Participant Incentive ($800/kW of Demand Savings):
Participant Incentive
=
=
3.5 kW x $800/kW
$ 2,800.00
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
Participant Incentive
=
=
1,563 kWh
$ 156.00
x
$ 0.10/kWh
Maximum Allowable Participant Incentive (50% of Total Eligible Costs for the Project)
Participant Incentive
=
=
$ 12,000.00
$ 6,000.00
x
50%
The Participant Incentive is the greater value between the calculated incentive based on kW and kWh
savings, subject to a maximum 50% of total eligible costs for the project. Therefore, the total incentive
for this project is $2,800.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Page 64 of 66
Version 5.0 - Retrofit Program - Unitary A/C Engineering Worksheet - December 5, 2014
Applicant and Space Information
Company Name:
Project Description:
Calculator Description:
Calculator Sheet Number:
Total Number of Calculator Sheets:
Account Number:
Select Reference Facility:
Facility Description:
Community Centre
Load Duration Curve
% Time
9%
9%
22%
31%
20%
8%
2%
0%
0%
0%
Default
15%
14%
12%
14%
14%
15%
10%
4%
1%
0%
% Time
% Load
0 - 10%
10 - 20%
20 - 30%
30 - 40%
40 - 50%
50 - 60%
60 - 70%
70 - 80%
80 - 90%
90 - 100%
18%
16%
14%
12%
10%
8%
6%
4%
2%
0%
% Capacity
100%
System Operating Schedule - Cooling Season Only
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
Season 1
January
December
On Time
10:00 AM
10:00 AM
10:00 AM
10:00 AM
10:00 AM
10:00 AM
10:00 AM
Annual Holidays (#days)
Annual Operating Hours
Season 2
1
31
Off time
8:59 PM
8:59 PM
8:59 PM
8:59 PM
8:59 PM
4:59 PM
4:59 PM
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
Season 3
On Time
Off time
From:
To:
Average
Monday
Tuesday
Wednesday
Thursday
Friday
Saturday
Sunday
On Time
Off time
9
3506
Floor Area
Floor Area Served By AC Unit (m2):
400
Climate
Select the region which best represents the climate at the building location:
Eastern Ontario - (eg Ottawa)
Existing AC Units
Unit Type 1
Manufacturer / Series / Model:
Capacity (BTU/h):
Quantity
2
EER:
72,000
8.9
Unit Type 2
Manufacturer / Series / Model:
Capacity (BTU/h):
Quantity
EER:
Unit Type 3
Manufacturer / Series / Model:
Capacity (BTU/h):
12,000 BTU/h = 1 Ton
Database of equipment with EER ratings:
http://oee.nrcan.gc.ca/residential/business/manufacturers/search/large-air-conditioners-search.cfm
Quantity
EER:
Replacement AC Units
Unit Type 1 (Replaces Existing Unit Type 1)
Manufacturer / Series / Model:
Capacity (BTU/h):
EER:
72,000
Unit Type 2 (Replaces Existing Unit Type 2)
Manufacturer / Series / Model:
Capacity (BTU/h):
12.00
EER:
Unit Type 3 (Replaces Existing Unit Type 3)
Manufacturer / Series / Model:
Capacity (BTU/h):
12,000 BTU/h = 1 Ton
Database of equipment with EER ratings:
http://oee.nrcan.gc.ca/residential/business/manufacturers/search/large-air-conditioners-search.cfm
EER:
Economic Values
$
0.10
Blended Cost of Power ($/kWh)
g
g pp
p
limited to the following list. Please enter the Eligible Costs as applicable.
$
Project Costs Breakdown
y
6.00
p
Estimated Monthly Demand ($/kW)
p
10,000.00 Actual costs of the equipment purchased and installed
2,000.00 Actual costs of labour for the installation of the equipment by suppliers
Actual costs to dispose of or decommission the replaced equipment
Actual costs of inspections of the Project as may be required pursuant to Laws and Regulations
$
12,000.00 TOTAL ELIGIBLE COSTS FOR THE PROJECT
For certainty, costs which are not eligible to be included in Eligible Costs include:
g
$
$
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Unitary A/C Worksheet
System Design Assumptions
Tab 3 of 4
Page 65 of 66
Version 5.0 - Retrofit Program - Unitary A/C Engineering Worksheet - December 5, 2014
PROJECT ENGINEERING ESTIMATES
This section highlights the demand and energy consumption for the Base Case and Energy Efficient Case. From this data, the Energy Savings and Demand Savings associated with implementing the
energy efficient option are calculated.
Base Case
Measure
Energy Efficient
Case Measure
Savings
Summary
Maximum Summer Peak Period Demand (kW)
13.4
9.9
3.5
(Occurs During Summer On-Peak Period)
Average Summer Peak Demand (kW)
5.1
3.8
1.3
(Summer On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
38%
38%
38%
Maximum Winter Peak Period Demand (kW)
0.0
0.0
0.0
(Occurs During Winter On-Peak Period)
Average Winter Peak Demand (kW)
0.0
0.0
0.0
(Winter On-Peak Energy/On-Peak Hours)
Average to Maximum Ratio (%)
0%
0%
0%
Annual Electricity Consumption (kWh)
6,051
4,488
1,563
PROJECT ECONOMICS
Based on cost information, entered by the user, along with incentive amounts, the project economics are summarized.
Assumed Blended Electricity Rate ($/kWh):
$
0.100
Assumed Demand Rate ($/kW)
$
6.00
156
Estimated Annual Energy Savings ($/year):
$
Other Savings (Cost) ($/year):
$
21
Estimated Total Annual Savings ($/year):
$
177
Demand Savings1(kW) for the purpose of calculating the Participant
Incentive
3.5
Energy Savings2 (kWh) for the purpose of calculating the Participant
Incentive
1,563
NOTE : These values go to the saveONenergy RETROFIT
Program Application under the Site and Project Details of
the Engineered Approach - Demand (kW) and Energy
(kWh) Savings
Total Eligible Costs for the Project($):
$
12,000
Calculated kW Participant Incentive ($800/kW of Demand Savings)
$
2,800
Calculated kWh Participant Incentive ($0.10/kWh of Energy Savings)
$
156
Maximum Allowable Participant Incentive (50% of Total Eligible Costs for the Project)
$
6,000
Estimated Participant Incentive Amount3:
$
2,800
Simple Payback (without Participant Incentive)
67.8
Simple Payback (with Participant Incentive)
51.9
LDC QC & DIAGNOSTICS
This section displays some checks that can be used to identify if the savings calculated are realistic, with respect to the facility consumption
Peak kW Savings - Percent of Facility Summer Peak Demand
0.4%
Facility Total kWh
Average kW Savings - Percent of Summer Peak Demand
0.1%
Max Summer kW
3,576,034
960
Percent of Facility Winter Peak Demand
0.0%
Max Winter kW
446
Average Savings - Percent of Winter Peak Demand
0.0%
Percent of Facility Total Annual Electricity Consumption
0.0%
CONDITIONS AND DISCLAIMERS
Note 1: Demand Savings (kW) are the maximum reduction in electricity demand between the Base Case and the Energy Efficient Case occurring in the same hour between 11 am to 5 pm on business
days, June 1 through September 30. For Measures that are weather dependent, Demand Savings shall be considered as occurring at peak design load conditions.
Note 2: Energy Savings (kWh) are those electricity savings achieved over the course of the first year after the completion of a Project.
Note 3: Estimated Participant Incentive Amount is calculated as the maximum of Calculated kW Participant Incentive and Calculated kWh Participant Incentive, with a Maximum Allowable Participant
Incentive at 50% of Total Eligible Costs for the Project.
Note 4: The Participant Incentive Amount indicated in this Engineering Worksheet is added up to the Prescriptive and Custom Incentive Amounts, if there are any. Likewise, the Project Cost in this
Engineering Worksheet is added up to the Prescriptive and Custom Project Costs, if there are any, summing it up to the Total Project Cost which would, in turn, serve as the basis for the 50% Project
Cost Cap
A mark of the Province of Ontario protected under Canadian trademark law.
Used under sublicence.
OM
Official Mark of the Independent Electricity System Operator. Used under licence.
APPENDIX A - Technical User Guide Manual for the Retrofit Engineered Worksheets - JAN 2015
Unitary A/C Worksheet
Outputs
Tab 4 of 4
Page 66 of 66
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Suite 1600
Toronto, Ontario
M5H 1T1
For inquiries regarding this User Guide Manual, please send them to
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