Energy Conservation and Demand Management Plan...Town of Innisfil Energy Conservation and Demand...

1 Town of Innisfil Energy Conservation and Demand Management Plan

Energy Conservation and

Demand Management Plan

Prepared By: George Shaparew

Prepared on May 30, 2014


Table of Contents

Page

1. Introduction and Background 3

2. Executive Summary 4

3. Goals and Objectives for Conserving Energy 5

4. Previous, Current & Proposed Measures with 6

Cost and Savings Estimates

5. Renewable Energy Generation Facility 14

6. Ground Source Energy Harnessed 15

7. Thermal Energy Harnessed 15

8. Future Heat Pump or Thermal Air or Water Technology 15

9. Length of Time Measures will be in Place 15

10. Natural Gas Use Mitigation 16

11. Fleet Fuel Use Mitigation 17

Confirmation of Approval by Senior Management Appendix A

Ontario Regulation 397/11 Appendix B

Energy Assessment Report by Innisfil Hydro Appendix C

10 Year Fleet Plan Appendix D

2011 Annual Energy Consumption Appendix E


1. Introduction and Background

The Ontario Provincial Government has initiated regulations to help public agencies

better understand and manage their energy needs. As part of this commitment, Ontario

Regulation 377/11 under the Green Energy Act 2009 requires public agencies –

municipalities, municipal service boards, school boards, universities, colleges and

hospitals - to report their energy consumption and greenhouse gas (GHG) emissions

annually beginning in 2013 and to develop and implement energy Conservation and

Demand Management (CDM) plans staring in 2014.


2. Executive Summary

The Town of Innisfil has been active with regard to energy conservation initiatives.

Using 2008 as a base-line, the following major projects have been undertaken or

planned as follows:

2008 – Traffic light LED retrofit

– New Town Hall, LEED Silver, Old building demolished

– New Recreation Complex, LEED Silver

– Water Plant, expansion using modern energy use standards

2009 – New Cookstown Library, LEED Silver, PV panels with geothermal HVAC

– Photo Voltaic (PV) powered gateway sign lighting

2010 – Police Building, refurbish and expand using modern energy use standards

2011 – 10 kW PV Solar Array electricity generator

2012 – IRC, lighting retrofit

2013 – Water and Wastewater plants, demand management program

– Energy Assessment Report provided by Innisfil Hydro

- Stroud and LeFroy arenas, lighting retrofit

2014 – New Innsifil Heights water pumping station, modern energy use standards

– Streetlights, LED streetlight conversions, 2814 HPS lights to be decommissioned

– New Salt Barn, with 100 kV – 250 kV PV roof top solar in 2015

2015 – New Operations Centre, Possibly LEED standards with 100kV – 250kV roof top solar

– New Cookstown Firehall, Possibly LEED standards

– New Lefroy Firehall, Possibly LEED standards

2017 – Water Plant Expansion using modern energy use standards

– New Fire Hall BBP, Possibly LEED standards

2018 – Waste water plant expansion started using modern energy use standards

– New Lefroy Library, Possibly LEED standards

Along with the major projects listed above, there were also 11 Small Business Lighting

Retrofit projects undertaken through Innisfil Hydro and the Ontario Power authority.

While major energy management initiatives have been completed, there is on-going

focus towards conservation and energy management throughout the five year term of

this plan.


3. Goals and Objectives for Conserving Energy

The Town of Innisfil has prepared an Energy Conservation and Demand Management

Plan that will fulfil the requirements of Ontario Regulation 397/11 and also achieve the

following objectives:

Categorize the achievements of past accomplishments,

Identify future opportunities for conserving energy,

Provide the leadership and guidance required for a culture of sustainability,

Provide a forum to explore new conservation trends and ideas,

Identify cost reductions associated with energy conservation, and

Identify best practices to reduce energy consumption and associated costs.

The Town of Innisfil is expected to grow from 34,000 people in 2014 to 56,000 people in

2031. With this type of growth on the horizon, it will be difficult to quantify energy

reduction goals because conservation and growth are diametrically opposed.

In areas where overall energy usage can be quantified without the influence of growth, a

5% reduction in overall energy intensity over the duration of the CDM plan is targeted.


4. Previous, Current & Proposed Measures with Cost and Savings

Estimates

The following measures have been separated between projects and saveONenergy programs through Innisfil Hydro and the Ontario Power Authority.

Previous Measures

2008

Traffic light LED retrofit. An estimated 10 traffic light intersections were retrofitted. Eight bulbs run continuously in one traffic light intersection. By saving 100W per bulb, the demand savings are 800W per traffic intersection and 8kW for all ten light intersections. The energy savings for ten traffic light intersections is estimated at 70,000 kWh per year.

New Town Hall, LEED Silver, Old building demolished. The New Town Hall is larger than the old one which was built in 1973. The new facility uses T5 lighting and current energy efficiency standards. The new Town Hall also meets current accessibility standards, unlike the old Town Hall. An energy savings comparison is not readily possible due to the inability of accessing old data.

New Recreation Complex, LEED Silver. This is a brand new facility with two ice pads, gymnasium, fitness centre, two pools, walking track, four soccer pitches and two ball diamonds. The ice surface compressors use ‘ice cube’ technology whereby the waste heat is used to heat the running track and pool water. There are no savings data available for this facility.

Water Plant expansion. The only lake based water plan had undergone an expansion to increase its capacity. The same water filtration technology was used and the building envelope was updated using modern energy use standards. There is no savings data available for this facility.

2009

New Cookstown Library, LEED Silver. The new library is much larger than the old one and includes 525W PV panels for demonstration purposes. The panels are not metered and are expected to produce 650 kWh per year. The HVAC system uses geothermal piping connected to heat pumps. An energy savings comparison is not readily possible due to the inability of accessing old data.

Photo Voltaic (PV) powered gateway sign. This sign was originally installed with 3 x 35W LED lights powered by 6 x 130W PV panels. The savings for being off grid is 384 kWh per year.


2010

Police Building. This building was originally a one story building of approximately 7,000 sq’. It was refurbished and expanded into a two story building using modern energy use standards. There are no savings data available for this facility.

2011

A 10 kW PV Solar Array generator was installed at 2147 Innisfil Beach Road. It is a self-supporting, sun tracking unit that generates 16,400 kWh per year. A 20 year agreement has been entered to for the sale of electricity with the Ontario Power Authority.

2012

IRC, Stroud and LeFroy arenas, replacement of metal halide lighting with fluorescent lighting

2013

An Energy Assessment Report was provided by Innisfil Hydro as part of an initiative to reduce energy costs and consumption. The full report is available in Appendix A. The report has 32 financial and energy savings recommendations which will be referenced for capital projects over the five year horizon of this plan. As a result of this report the Water plant, Wastewater plant and IRC have signed up for demand management incentives.

Stroud and LeFroy arenas, replacement of metal halide lighting with fluorescent lighting

Demand management programs were signed up with the OPA for the Water, Wastewater and IRC.

Current Measures

2014

New Innsifil Heights water pumping station. This pumping station has larger capacity and a larger reservoir as compared to the old one, which will be decommissioned. The new pumping station will use modern energy use standards and is expected to be in service in Q3 2014. There are no savings data available for this facility.

Streetlights, LED streetlight conversions. It is planned to replace 2814 HPS lights that will be decommissioned. The new lights will have an estimated off peak demand savings of 2.9MW with annual energy savings of 1,032,000 kWh. The new LED lights are expected to be in service in Q3, 2014.

PV Roof Top Analysis has been undertaken by Fluent Group Consulting Engineers Inc. They are undergoing a feasibility analysis for the new Salt Barn, the new Operations Centre and Innisfil Hydro’s new building on Town Campus. The analysis is expected to be completed in Q2 2014 with implementation in Q2 2016.


The Lakeshore Library is undergoing an expansion which is expected to be completed in 2015. Because the expansion is adjacent to an existing structure, LEED certification will not be explored but the building is designed with LEED principals including all LED lighting.

A new salt barn will be started utilizing modern energy efficiency standards.

Future Measurers

2015

New Salt Barn which will replace the old salt dome. It will provide superior salt management capabilities and will not be a large energy user. The primary energy load is anticipated to be lighting which will incorporate modern energy use standards. There is no savings data available for this facility.

New Operations Centre which will replace the old operations centre. It will be larger than the existing operations centre to meet future growth requirements. There is no savings data available for this facility. The operations centre is expected to include a vehicle maintenance facility which may include some light industrial electricity load. The facility is expected to include full natural gas electricity generation and incorporate modern use energy standards or LEED standards.

The LeFroy firehall (Station #2) will be replaced at the new location of 5th Line

and 20th SR. It shall incorporate modern use energy standards or LEED

standards.

The Cookstown firehall (Station #4) will be replaced at the new location beside

the existing location. It shall incorporate modern use energy standards or LEED

standards.

2017

The lake based water plant is scheduled to undertake an expansion which shall

incorporate modern use energy standards or LEED standards.

The new BBP firehall (Station #5) will be built. It shall incorporate modern use

energy standards or LEED standards.

2018

The lake based waste water plant is scheduled to undertake an expansion which

shall incorporate modern use energy standards or LEED standards.

A new Library is scheduled to be built in the village of LeFroy incorporating

modern use energy standards or LEED standards.


SaveONenergy Programs

Businesses across Ontario can benefit from an array of programs offered throughout

the province. There are energy-efficiency programs to assist organizations from the

smallest of retail stores to the largest industrial complexes. Programs to help fund

energy audits, to replace energy-wasting equipment or to pursue new construction that

exceeds our existing codes and standards. Businesses can also pursue incentives for

controlling and reducing their electricity demand at specific times. The bottom line is that

there are innovative programs that can help businesses reduce their electricity costs,

while helping Ontario defer the need to build new generation and reduce its

environmental footprint.

The Town of Innisfil has undertaken the following programs:

Retrofit Applications Underway (Submitted)

#125,293 – 2101 Innisfil Beach Road, Innisfil (Street Lighting Retrofit)

Lighting Retrofit:

1,509 95W HPS lights to 25W LED

976 130W HPS lights to 42W LED




Estimated kW Savings – 0kW

Estimated kWh Savings – 1,032,480 kWh

Incentive – $51,624

Small Business Lighting – Facilities Participated

Below is a list of Town facilities that have participated in the Small Business Lighting

program. It would require some additional work to get the actual measures installed at

each facility from Burman Energy and calculate the savings associated with them,

please let me know if this is information you would like to have.


Completed Retrofit Applications

#110,098 – 7315 Yonge Street, Innisfil (Innisfil Rec Centre) Lighting Retrofit: 5 175W exterior lights to 74W LED Wallpacks 32 400W metal halide fixtures to 54 3 lamp T5HO fixtures 15 400W metal halide fixtures to 6 lamp T5HO fixtures 168 400W metal halide fixtures to 4 lamp T5HO fixtures kW Savings – 51.095kW kWh Savings – 256,291.04kWh Incentive - $28,201.80 Project Completion Date – July 31, 2012 Prescriptive application, a portion of the savings calculated are using OPA prescriptive input assumptions.

#116,638 – 7883 Yonge Street, Innisfil (Stroud Arena and Curling Club) Lighting Retrofit (Arena) – 24 1000W metal halide fixtures to 12 lamp T5HO fixtures Lighting Retrofit (Curling Rink) – 45 400W metal halide fixtures to 4 lamp T5HO fixtures kW Savings – 14.067kW kWh Savings – 67,409.064 Incentive - $9,765 Project Completion Date – June 24, 2013 Was a prescriptive application, savings calculated using OPA prescriptive input assumptions.

#116,641 – 1354 Killarney Beach, Innisfil (Lefroy Arena) Lighting Retrofit – 50 400W metal halide fixtures to 4 lamp T5HO fixtures kW Savings – 7.95kW kWh Savings – 38,096.4kWh Incentive – $5,250 Project Completion Date – June 6, 2013 Was a prescriptive application, savings calculated using OPA prescriptive input assumptions.

#116,649 – 7315 Yonge, Innisfil (Innisfil Rec Centre – Running Track) Lighting Retrofit – 56 150W metal halide fixtures to 50W LED fixtures kW Savings – 7.8kW kWh Savings – 41,941kWh Incentive – $2,948 Project Completion Date – May 23, 2013 Was a prescriptive application, savings calculated using OPA prescriptive input assumptions.


#120,232 – 2101 Innisfil Beach Road, Innisfil (Innisfil Town Hall) Lighting Retrofit – 38 75W Incandescent pot lights to 9.4W LED’s kW Savings – 2.0938kW kWh Savings – 5431.302kWh Incentive - $874 Project Completion Date – September 5, 2013 Was a prescriptive application, savings calculated using OPA prescriptive input assumptions.

Retrofit Applications Underway (Submitted)

#125,293 – 2101 Innisfil Beach Road, Innisfil (Street Lighting Retrofit) Lighting Retrofit: 1,509 95W HPS lights to 25W LED 976 130W HPS lights to 42W LED 205 190W HPS lights to 64W LED 87 310W HPS lights to 101W LED 37 250W HPS lights to 82W LED Estimated kW Savings – 0kW Estimated kWh Savings – 1,032,480 kWh Incentive – $51,624

Future Retrofit Application Submissions The following three lighting projects that are planned at the following facilities. At this time applications have not been submitted until specific project details are available.

Lefroy Arena: 1354 Killarney Beach Road, Lefroy

Stroud Arena/Curling Club: 7883 Yonge St, Innisfil

WPCP: 1578 St. Johns Road, Innisfil


Small Business Lighting – Facilities Participated Below is a list of Town facilities that have participated in the Small Business Lighting program. It would require some additional work to get the actual measures installed at each facility from Burman Energy and calculate the savings associated with them, please let me know if this is information you would like to have.


Demand Response Agreements

Demand response programs compensate participating industrial and commercial

businesses for reducing their energy demand at specific times of power system

need. During such times wholesale market prices for electricity may be high, the power

system is experiencing large peaks in demand, or there is a greater risk to the reliability

of the electricity grid.

In 2013, the Town of Innisfil has entered into three demand response agreements with

the Ontario Power Authority as follows:

1. Water Treatment Plant

Address: 2155-25 Sideroad, Innisfil

Contracted DR: 100 kW

Equipment curtailed: low-lift pumps, high-lift pumps

2. Wastewater Plant

Address: 1578 St. John’s Road, Innisfil


Equipment curtailed: 2 sludge tank blowers

3. IRC

Address: 7315 Yonge Street, Innisfil


Equipment curtailed: 2 ice plant compressors, 2

dehumidifiers, and various small pumps


5. Renewable Energy Generation Facility

The Town of Innisfil has three photo Voltaic projects producing electricity as follows:

1. 780W off grid supplying the lighting at the Innisfil gateway sign, Highway 400 at

Innisfil Beach Road.

2. 525W behind the meter demonstration panels at the Cookstown Library.

3. 10kW MicroFIT solar tracking unit is at 2147 Innisfil Beach Road.

The Town is investigating three more Feed in Tariff (FIT) opportunities at the following

locations for 2015 and 2016:

1. 100 kW – 250 KW roof top, 7253 Yonge Street, new Operations Centre.

2. 100 kW – 250 kW roof top. 7247 Yonge Street, new salt barn.

3. 50 kW roof top, 7251 Yonge Street, New Innisfil Hydro head office and

operations centre.


6. Ground Source Energy Harnessed

The Town has one ground source heat pump in operation at the Cookstown library. In

December 2014, the Town is planning to purchase two buildings from Innisfil Hydro,

2073 & 2061 Commerce Park Drive. One of the buildings has a ground source heat

pump. There are no other ground source energy projects planned over the next five

years.

7. Thermal Energy Harnessed

The Town does not have any thermal energy harnessing by thermal air technology or

thermal water technology. There are no plans to do so within the next five years.

8. Future Heat Pump or Thermal Air or Water Technology

Within the next five years, there are no plans to operate heat pump technology, thermal

air technology or thermal water technology. When planning new developments, Town

Planning will be mindful of district energy options for residential, commercial and

institutional opportunities.

9. Length of Time Measures will be in Place

This five year plan is to be in place until the latest date of July 1, 2019. It may be

updated from time-to-time.


10. Natural Gas Use Mitigation

The Town of Innisfil does not have facilities that use large amounts of natural gas for

processing. Most facilities such as the Town Hall, Innisfil Recreational Complex and the

Water Treatment Plant are relatively new so old technologies are not present there for

retrofit applications. The water and wastewater plants were toured and it was

determined that natural gas is not used in any process, only space heating. The Innisfil

Recreation complex take advantage of compressor heat recovery so most fuel

mitigation opportunities have already been incorporated.

Enbridge Gas has provided a generic contact for their conservation programs.

Energy Solutions Consultant

Phone: 1-866-844-9994

Email: [email protected]

Over the five year term of this plan, Town staff are encouraged to investigate

conservation and demand management programs for the mitigation of natural gas use

within the Town of Innisfil’s facilities when equipment requires replacement.


11. Fleet Fuel Use Mitigation

The Town of Innisfil uses a large fleet of vehicles for providing services to the

community. While the primary purpose of those vehicle are for service dedication, staff

are encouraged to investigate the mitigation of fuel use for fleet purposes. A list of

opportunities are listed below but not limited to the following:

Selecting smaller or lighter vehicles

Utilizing anti-idling technologies

Selecting vehicles that use more efficient fuel

Selecting hybrid technologies

Increasing fleet longevity will postpone energy use requirements to fabricate new

vehicles. It takes the energy equivalent of 260 gallons of gasoline to make a

3,000 lb car1, and

Promote policies to discourage aggressive driving, minimize idling and

encourage regular vehicle maintenance.

A list of Town vehicles has been attached in Appendix D along with the planned

succession of vehicles over a ten year period. While creating annual budgets, Town

staff shall review the vehicle replacement plan with the vision of mitigating fuel use for

the benefit of cost reduction and lowering carbon emissions.

1 http://sierraclub.typepad.com/greenlife/2013/10/hey-mr-green-how-much-energy-to-manufacture-new-

car.html%20

Appendix A

Approval by the Town of Innisfil’s Senior Management

Appendix B

Ontario Regulation 397/11

ONTARIO REGULATION 397/11

made under the

GREEN ENERGY ACT, 2009

Made: August 17, 2011

Filed: August 23, 2011

Published on e-Laws: August 25, 2011

Printed in The Ontario Gazette: September 10, 2011

ENERGY CONSERVATION AND DEMAND MANAGEMENT PLANS

Definitions

1. In this Regulation,

“municipal service board” means,

(a) a municipal service board or joint municipal service board established or

continued under the Municipal Act, 2001,

(b) a city board or joint city board established or continued under the City of

Toronto Act, 2006, or

(c) a joint board established in accordance with a transfer order made under the

Municipal Water and Sewage Transfer Act, 1997; (“commission de services

municipaux”)

“post-secondary educational institution” means a university in Ontario, a college of

applied arts and technology in Ontario or another post-secondary educational

institution in Ontario, if the university, college or institution receives an annual

operating grant; (“établissement d’enseignement postsecondaire”)

“public hospital” means,

(a) a hospital within the meaning of the Public Hospitals Act, or

(b) the University of Ottawa Heart Institute/Institut de cardiologie de l’Université

d’Ottawa; (“hôpital public”)

“school board” means a board within the meaning of the Education Act. (“conseil

scolaire”)

Application

2. Sections 4, 5 and 6 apply only to public agencies prescribed by section 3.

Public agencies

3. The following are prescribed as public agencies for the purposes of the Act:

1. Every municipality.

2. Every municipal service board.

3. Every post-secondary educational institution.

4. Every public hospital.

5. Every school board.

Energy conservation and demand management plans

4. (1) A public agency shall prepare, publish, make available to the public and

implement energy conservation and demand management plans or joint plans in

accordance with sections 6 and 7 of the Act and with this Regulation.

(2) An energy conservation and demand management plan is composed of two

parts as follows:

1. A summary of the public agency’s annual energy consumption and greenhouse

gas emissions for its operations.

2. A description of previous, current and proposed measures for conserving and

otherwise reducing the amount of energy consumed by the public agency’s

operations and for managing the public agency’s demand for energy, including

a forecast of the expected results of current and proposed measures.

Summary of annual energy consumption and greenhouse gas emissions

5. (1) Subject to subsection (2), a summary of the public agency’s annual energy

consumption and greenhouse gas emissions must include a list of the energy consumption

and greenhouse gas emissions for the year with respect to each of the public agency’s

operations that are set out in Table 1 of this Regulation for the type of public agency to

which the public agency belongs and that are conducted in buildings or facilities the

public agency owns or leases that,

(a) are heated or cooled and in respect of which the public agency is issued the

invoices and is responsible for making the payments for the building or

facility’s energy consumption; or

(b) are related to the treatment or pumping of water or sewage, whether or not the

building or facility is heated or cooled, and in respect of which the public

agency is issued the invoices and is responsible for making the payments for

the building or facility’s energy consumption.

(2) If only part of a building or facility where an operation is conducted is heated

or cooled, the public agency’s summary referred to in subsection (1) must only include

energy consumption and greenhouse gas emissions for the part of the building or facility

where the operation is conducted that is heated or cooled.

(3) The public agency’s summary referred to in subsection (1) must be prepared

using the form entitled “Energy Consumption and Greenhouse Gas Emissions Template”

that is available from the Ministry and must include the following information and

calculations for each of the public agency’s operations:

1. The address at which the operation is conducted.

2. The type of operation.

3. The total floor area of the indoor space in which the operation is conducted.

4. A description of the days and hours in the year during which the operation is

conducted and, if the operation is conducted on a seasonal basis, the period or

periods during the year when it is conducted.

5. The types of energy purchased for the year and consumed in connection with

the operation.

6. The total amount of each type of energy purchased for the year and consumed in

connection with the operation.

7. The total amount of greenhouse gas emissions for the year with respect to each

type of energy purchased and consumed in connection with the operation.

8. The greenhouse gas emissions and energy consumption for the year from

conducting the operation, calculating,

i. the annual mega watt hours per mega litre of water treated and distributed,

if the operation is a water works,

ii. the annual mega watt hours per mega litre of sewage treated and

distributed, if the operation is a sewage works, or

iii. per unit of floor space of the building or facility in which the operation is

conducted, in any other case.

(4) If a public agency conducts, in the same building or facility, more than one

operation set out in Table 1 of this Regulation for the type of public agency to which the

public agency belongs, it shall make a reasonable allocation of the amount of energy

purchased and consumed for the year among each of those operations.

(5) In preparing its annual Energy Consumption and Greenhouse Gas Emission

Template, a public agency may exclude its energy consumption and green house gas

emissions relating to its temporary use of an emergency or back-up generator in order to

continue operations.

(6) On or before July 1, 2013, every public agency shall submit to the Minister,

publish on its website and intranet site, if it has either or both, and make available to the

public in printed form at its head office the public agency’s Energy Consumption and

Greenhouse Gas Emission Template for operations conducted in 2011.

(7) On or before July 1 of each year after 2013, every public agency shall submit to

the Minister, publish on its website and intranet site, if it has either or both, and make

available to the public in printed form at its head office the public agency’s Energy

Consumption and Greenhouse Gas Emission Template for operations conducted in the

year following the year to which the last annual Template related.

(8) The following information, if applicable, must also be submitted, published and

made available to the public with every Energy Consumption and Greenhouse Gas

Emission Template:

1. If the operation is a school operated by a school board,

i. the number of classrooms in temporary accommodations at the school

during the year, and

ii. whether there is an indoor swimming pool in the school.

2. If the public agency is a public hospital, whether a facility operated by the

public hospital is a chronic or acute care facility, or both.

Energy conservation and demand management measures

6. (1) On or before July 1, 2014, every public agency shall publish on its website

and intranet site, if it has either or both, and make available to the public in printed form

at its head office,

(a) the information referred to in subsection 6 (5) of the Act with respect to each of

the public agency’s operations set out in Table 1 of this Regulation for the type

of public agency to which the public agency belongs;

(b) the information referred to in paragraph 2 of subsection 4 (2) of this Regulation

with respect to each of the public agency’s operations set out in Table 1 of this

Regulation for the type of public agency to which the public agency belongs;

and

(c) the following information:

(i) information on the public agency’s annual energy consumption during the

last year for which complete information is available for a full year,

(ii) the public agency’s goals and objectives for conserving and otherwise

reducing energy consumption and managing its demand for energy,

(iii) the public agency’s proposed measures under its energy conservation

and demand management plan,

(iv) cost and saving estimates for its proposed measures,

(v) a description of any renewable energy generation facility operated by the

public agency and the amount of energy produced on an annual basis by

the facility,

(vi) a description of,

(A) the ground source energy harnessed, if any, by ground source heat

pump technology operated by the public agency,

(B) the solar energy harnessed, if any, by thermal air technology or

thermal water technology operated by the public agency, and

(C) the proposed plan, if any, to operate heat pump technology,

thermal air technology or thermal water technology in the future,

(vii) the estimated length of time the public agency’s energy conservation

and demand management measures will be in place, and

(viii) confirmation that the energy conservation and demand management

plan has been approved by the public agency’s senior management.

(2) In addition to publishing and making available the required information with

respect to the operations mentioned in clauses (1) (a) and (b), a public agency may also

publish information with respect to any other operation that it conducts.

(3) On or before July 1, 2019 and on or before every fifth anniversary thereafter,

every public agency shall publish on its website and intranet site, if it has either or both,

and make available to the public in printed form at its head office all of the information

that is required to be published and made available under subsection (1), the Energy

Consumption and Greenhouse Gas Emission Template that is required to be submitted

and published on or before July 1 of that year and the following information:

1. A description of current and proposed measures for conserving and otherwise

reducing energy consumption and managing its demand for energy.

2. A revised forecast of the expected results of the current and proposed measures.

3. A report of the actual results achieved.

4. A description of any proposed changes to be made to assist the public agency in

reaching any targets it has established or forecasts it has made.

(4) If a public agency initiated energy conservation measures or energy demand

management measures before July 1, 2014, the public agency may also include in its first

plan information on the results of those measures.

TABLE 1

Column 1 Column 2 Column 3

Item Type of public agency Operation

1. Municipality 1. Administrative offices and related facilities, including

municipal council chambers.

2. Public libraries.

3. Cultural facilities, indoor recreational facilities and community

centres, including art galleries, performing arts facilities,

auditoriums, indoor sports arenas, indoor ice rinks, indoor

swimming pools, gyms and indoor courts for playing tennis,

basketball or other sports.

4. Ambulance stations and associated offices and facilities.

5. Fire stations and associated offices and facilities.

6. Police stations and associated offices and facilities.

7. Storage facilities where equipment or vehicles are maintained,

repaired or stored.

8. Buildings or facilities related to the treatment or pumping of

water or sewage.

9. Parking garages.

2. Municipal service board 1. Buildings or facilities related to the treatment or pumping of

water or sewage.

3. Post-secondary educational institution 1. Administrative offices and related facilities.

2. Classrooms and related facilities.

3. Laboratories.

4. Student residences that have more than three storeys or a

building area of more than 600 square metres.

5. Student recreational facilities and athletic facilities.

6. Libraries.

7. Parking garages.

4. School board 1. Schools.

2. Administrative offices and related facilities.

3. Parking garages.

5. Public hospital 1. Facilities used for hospital purposes.

2. Administrative offices and related facilities.

Commencement

7. This Regulation comes into force on the later of January 1, 2012 and the

day it is filed.

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Appendix C

Energy Assessment Report

ENERGY ASSESSMENT REPORT

TOWN OF INNISFIL

WATERWORKS FACILITIES

WASTEWATER FACILITIES

RECREATIONAL FACILITIES

Prepared for: TOWN OF INNISFIL

Prepared by: Khaled Hamel, Roving Energy Manager

INNISFIL HYDRO DISTRIBUTION SYSTEMS LIMITED

January 2013

CONTENTS

1- EXECUTIVE SUMMARY 1

2- INTRODUCTION & METHODOLOGY 6

3- FACILITY DESCRIPTION 7

4- ENERGY BASELINE 12

5- ENERGY CONSERVATION MEASURES (ECMS) - RECOMMENDATIONS AND

IMPLEMENTATION 39

6- AVAILABLE INCENTIVES AND FUNDING SOURCES 44

7- APPENDICES 47

7.1- HISTORICAL DATA ANALYSIS

7.2- DEMAND RESPONSE PROVIDERS

1 TOWN OF INNISFIL – ENERGY ASSESSMENT REPORT

XECUTIVE SUMMARY:

1- EXECUTIVE SUMMARY

As part of the initiative to reduce energy costs and consumption, the Town of Innisfil has secured

the services of Innisfil Hydro Distribution’s Roving Energy Manager (REM) to perform an energy

assessment for their waterworks, wastewater treatment and recreational facilities in an effort to

develop comprehensive Energy Conservation Measures (ECMs).

The REM visited the Water Treatment Plant (WTP) and pumping stations on November 16th and

December 11th, 2012. The wastewater treatment facilities were visited on November 23rd, 2012;

the tour of the recreational facilities was done on November 19th and December 13th, 2012. As a

result of the site visits and evaluation of the historical energy usage of the facilities, the REM was

successful in identifying various facility system components that present feasible opportunities

for energy savings measures.

The REM has also evaluated the potential for participating in available demand curtailment

programs in Ontario to be implemented at the Water Treatment Plant. The operating

requirements and schedules of the various pumps were investigated.

The recommended ECMs were measured through a simple payback analysis. The simple payback

period was determined upon an estimated capital/construction cost, projected annual energy

savings estimates, and the integration of eligible saveONenergy incentive programs. ECMs that

have a payback period of 5 years or less are recommended.

1.1- RECOMMENDED ECMS The following tables present estimated financial and energy savings summaries and the

recommended ECMs identified for equipment and system components at the WTP and water

pumping facilities, wastewater treatment facilities, and at the recreational buildings.


1.2- FINANCIAL SUMMARY TABLES

ENERGY CONSERVATION MEASURES

WATER TREATMENT PLANT & PUMPING STATIONS

ECM # Description Estimated

Costs ($)

Estimated

Incentives

($)

Projected

Annual

Savings ($)

Average

Simple

Payback

Period (years)

ECM#1 WTP

High-Lift Pumps; VFDs $80,000 $20,000 $10,000 6 years

ECM#2 WTP

Backwash Pumps; Duty Cycle Change

$2,000

--

$5,000 0.4 year

ECM#3 WTP

HLP & LLP-Demand Curtailment; DR3

--

$25,600 --- 0 year

ECM#4 WTP

Off-Peak operation-Interval Meter

--

-- $5,000 0 year

ECM#5

WTP

Replace (8) MH400 and (60) MH175 Lamps with (8) 4-Lmap F54T5HO and (60) 4-Lamp High Performance F32T8

$10,000 $6,840 $2,400 1.3 year

ECM#6 Stroud Water ST

Fire Pump-Demand Curtailment; DR3

--

$6,400 -- --

Table 1.1 – WTP & Pump Stations Financial Summary Table

WASTEWATER TREATMENT FACILITIES


Costs ($)

Estimated

Incentives

($)

Projected

Annual

Savings ($)

Average

Simple

Payback

Period (years)

ECM#7 Lakeshore Plant

Air Blower; VFDs $75,000 $24,000 $20,000 2.5 years

Table 1.2 – Wastewater Treatment Financial Summary Table




Costs ($)

Estimated

Incentives

($)

Projected

Annual

Savings ($)

Simple

Payback

Period (years)

ECM#8 IRC

Dectron; VFDs /Motor Blower 25 hp & 7.5 hp

$6,000 $1,740 $1,400 3 years

ECM#9

IRC HRU1; VFD on Return/Exhaust Fan (7.5 hp)

$1,500 $400 $400 2.75 years

ECM#10

IRC Replace (46) Lamps (Ice Rink #2) with (46) 4-Lamp F25T5 Fixtures

$6,000 $1,480 $2,000 2 years

ECM#11

Stroud Arena

Refrigeration Plant; VFD /Condenser Water Supply Pump (7.5 hp)

$1,500 $400 $300 3.6 years

ECM#12 Stroud Arena

Cooling Tower; VFDs on Condenser Fan (15 hp)

$3,000 $805 $600 3.6 years

ECM#13

Stroud Arena Replace (24) MH1000 Lamps in Ice Rink with (48) 4-Lamp F54T5HO Fixtures

$10,000 $5,000 $2,500 2.4 years

ECM#14

Stroud Arena Replace (45) MH400 Lamps in Curling Club with (45) 4-Lamp F54T5HO Fixtures

$9,000 $4725 $2,000 2.7 years

ECM#15

Stroud Arena

Install Occupancy Sensor in Banquet Room

$200 $40 $200 0.8 year

ECM#16

Lefroy Arena Replace (50) MH400 Lamps in Curling Club with (50) 4-Lamp F54T5HO Fixtures

$10,000 $5250 $1,600 3.6 years

Table 1.3 – Recreational Facilities Financial Summary Table


1.3- ENERGY SAVINGS SUMMARY TABLES

ENERGY CONSERVATION MEASURES

WATER TREATMENT PLANT & PUMPING STATIONS

ECM # Description

Annual Energy and Demand Reduction

Demand (kW) Electric

Consumption (kWh)

Natural Gas (Btu)

ECM#1 WTP

High-Lift Pumps; VFDs 50 kW 100,000 kWh --

ECM#2 WTP

Backwash Pumps; Duty Cycle Change

40 kW -- --

ECM#3 WTP

HLP & LLP-Demand Curtailment; DR3

200 kW -- --

ECM#4 WTP

Off-Peak operation-Interval Meter

-- -- --

ECM#5

WTP

Replace (8) MH400 and (60) MH175 Lamps with (8) 4-Lmap F54T5HO and (60) 4-Lamp High Performance F32T8

6 kW 17,000 kWh

ECM#6 Stroud Water ST

Fire Pump-Demand Curtailment; DR3

50 kW

-- --

Table 2.1 – WTP & Pump Stations Estimated Energy Savings Summary Table

WASTEWATER TREATMENT FACILITIES

ECM # Description



Consumption (kWh)

Natural Gas (Btu)

ECM#7 Lakeshore Plant

Air Blower; VFDs 30 kW 150,000 kWh --

Table 2.2 – Wastewater Treatment Estimated Energy Savings Summary Table



ECM # Description



Consumption (kWh)

Natural Gas (Btu)

ECM#8 IRC

Dectron; VFDs /Motor Blower 25 hp & 7.5 hp

4.8 kW 13,000 kWh --

ECM#9 IRC HRU1; VFD on Return/Exhaust Fan (7.5 hp)

1.1 kW 6,000 kWh --

ECM#10

IRC Replace (46) Lamps (Ice Rink #2) with (46) 4-Lamp F25T5 Fixtures

3.7 kW 20,000 kWh --

ECM#11

Stroud Arena

Refrigeration Plant; VFD /Condenser Water Supply Pump (7.5 hp)

1.12 kW 2,000 kWh

ECM#12 Stroud Arena

Cooling Tower; VFDs on Condenser Fan (15 hp)

2.2 kW $3,500 kWh --

ECM#13

Stroud Arena Replace (24) MH1000 Lamps in Ice Rink with (48) 4-Lamp F54T5HO Fixtures

14.35 kW 20,000 kWh --

ECM#14

Stroud Arena Replace (45) MH400 Lamps in Curling Club with (45) 4-Lamp F54T5HO Fixtures

9.42 kW 13,000 kWh --

ECM#15 Stroud Arena

Install Occupancy Sensor in Banquet Room

-- 2,500 kWh

ECM#16

Lefroy Arena Replace (50) MH400 Lamps in Curling Club with (50) 4-Lamp F54T5HO Fixtures

10.45 kW 10,000 kWh --

Table 2.3 – Recreational Facilities Estimated Energy Savings Summary Table


2- INTRODUCTION & METHODOLOGY

As part of the initiative to reduce energy cost and consumption, the Waterworks Operations

division of the Town of Innisfil has secured the services of Innisfil Hydro Distribution Limited’

Roving Energy Manager (REM) to perform an energy assessment for their Waterworks facilities

in an effort to develop comprehensive Energy Conservation Measures (ECMs).

The energy use and savings analysis is performed at the Customer’s facility in a coordinated fashion

in order to determine the feasibility of the installation and implementation of energy conservation

measures at the facility and the integration of eligible provincial rebate programs. The various

stages conducted under this Energy Assessment are:

- Collect general facility information

- Inventory existing electrical load equipment

- Establish base year electricity consumption, estimate loading and usage of major end uses

- Develop list of potential Energy Conservation Measures (ECM’s)

- Select recommended ECM’s and provide costs and savings estimates

- Develop the Energy Assessment Report

Figure 1 is a flowchart representation of the phases undertaken by the REM to prepare the Energy

Assessment Report

Figure 1 – Energy Assessment Process


3- FACILITY DESCRIPTION

3.1- WATER TREATMENT PLANT & WATER PUMP STATIONS

3.1.1- WATER TREATMENT PLANT

The Water Treatment Plant draws water from Lake Simcoe through a 900mm diameter intake

piping, approximately 373 meters offshore and 11 meters below the lake surface.

Three 100 hp Low Lift turbine pumps are provided to transfer the screened raw water from the

lake to the water treatment plant, to a maximum rate 28,340 m3/day.

At the plant, five treatment units are provided each consists of an up-flow clarifier and a filter.

The clarified water flows into the filter compartment and then the treated water exits through a

grid of pipe work to two clear wells and four contact chambers.

The High Lift pumps and Backwash pump well are located at the end of the clear wells. Four

equally sized 125 hp high lift turbine pumps are placed over the wells and pump treated water to

the distribution system and/or the reservoir. The maximum daily flow of the Water Treatment

Plant is 25,797 m3.

The reservoir provides storage volumes for equalization and maintenance of system storage, fire

storage and emergency use.

The plant and reservoir also supplement the water supply to the Town of Bratford West

Gwillimbury via the water transmission main that discharges from the Alcona Reservoir.

The Alcona Reservoir characteristics are described below:

Construction: reinforced concrete Capacity: 8,700 m3 Cells: 2; Cell A and Cell B Equalization storage volume: 3,505 m3 Fire storage volume: 3,455 m3 Emergency storage volume: 1,740 m3


3.1.2- PUMP STATIONS

The booster and distribution pumping facilities include the Zone 2 Booster station, Stroud Water

pump station, MURF (Multi-Use Recreational facility) Reservoir station, Lakeshore Reservoir

Booster, and the Booster 3rd Line station.

Zone 2 Booster Station:

The Zone 2 Booster Station includes three high lift pumps (HLP) on variable speed drive, one max

duty pump for fire and emergency needs only, and a standby emergency generator. The station is

designed to serve a new development in the near future and currently runs on the 20 hp HLP#4

operated 24 hours a day.

Stroud Water Station:

The Stroud Water Station includes three high lift pumps (HLP) and one fire pump that can be

operated in high demand periods and/or backwash operation. The facility also houses three

submersible well pumps, four electric heaters, twenty 2-lamp T12 fixtures for lighting and a

standby emergency generator.

MURF Station:

The MURF Station includes two high lift pumps (HLP) on variable speed drive, one 50hp pump

for fire and emergency needs only, and a standby emergency generator. The station also consists

of two separate sewage pumps (wastewater facility# 7).

Lakeshore Reservoir Booster Station:

The Lakeshore Reservoir Booster Station includes two 15 hp pumps that provide water to the

Innisfil Recreational Centre and to the irrigation system at night, five electric heaters, six 2-lamp

T8 fixtures, and a standby emergency generator.

Third Line Booster station:

Finally, the 3rd Line Booster station, increase pressure and pumps water to the Bradford

reservoir, includes two equally sized 150 hp High Lift pumps that are usually not used, two 50 hp

High Lift pumps with only one pump running most of the time, and a 250 kVA standby

emergency generator.


Figure 2 blow illustrates the Town of Innisfil water distribution network.

Figure 2: Water Distribution Network – Town of Innisfil


3.2- WASTEWATER FACILITIES

3.2.1- LAKESHORE WASTEWATER PLANT

The Lakeshore Wastewater Plant is a 24-hour run facility and the details of the end use

equipment can be found in section 4.2.1 of this report. The station also includes a 406 kVA


3.2.2- COOKSTOWN WASTEWATER PLANT

The Cookstown Wastewater Plant is a 24-hour run facility and the details of the end use

equipment can be found in section 4.2.2 of this report. The station also includes a 68.8 kVA


3.2.3- SEWAGE PUMPING STATIONS

Sewage Station 1:

The Sewage Station #1 includes three 100 hp pumps; two pumps run on variable speed drives,

and the third runs on constant speed, five electric heaters, and a 250 kVA standby emergency

generator.

Sewage Station 2:

The Sewage Station #2 consists of two 7.5 kW submersible sewage pumps and a 52 kVA standby

emergency generator.

Sewage Station 3:

The Sewage Station #3, similar to Sewage Station #1, includes three 100 hp pumps; two pumps

run on variable speed drives, and the third runs on constant speed, five electric heaters, and a

250 kVA standby emergency generator.

Sewage Station 4:

The Sewage Station #3 includes three 50 hp pumps -two of the pumps run on variable speed

drives, and the other pump run by a constant speed motor-, five electric heaters, and a 125 kW



Sewage Station 5:

The Sewage Station #5 consists of two 7.5 hp submersible sewage pumps with alternate duty,

one 5 kW heater, and a 38 kVA standby emergency generator.

Sewage Station 7:

The Sewage Station #7 consists of two 7.5 hp submersible sewage pumps with alternate duty.

3.3- RECREATIONAL FACILITIES

3.3.1- INNISFIL RECREATIONAL CENTRE

The Innisfil Recreational Centre (IRC) is main recreational facility in the Town of Innisfil

originally commissioned in 2008. The IRC has two NHL sized ice pads, two swimming pools,

fitness centre, gymnasium, and meeting rooms. The outside grounds hosts four soccer pitches

and two baseball diamonds and associated parking. The details of the end use equipment can be

found in section 4.3.1 of this report.

3.3.2- STROUD ARENA

The Stroud Arena has one hokey ice pad, one curling club, and a banquet hall. The details of the

end use equipment can be found in section 4.3.2 of this report.

3.3.3- LEFROY ARENA

The Lefroy Arena has one hokey ice pad, one curling club, and a banquet hall. The details of the

end use equipment can be found in section 4.3.3 of this report.


4- ENERGY BASELINE The first step in the energy assessment process is the collection and analysis of the buildings

current and historical energy usage and associated utility costs.

For water treatment facilities, wastewater plants, and recreational centres, the majority of the

energy consumed is electric. Electricity is charged upon two basic components: electrical

consumption (kWh) and electrical demand (kW). The charge for energy is based on the amount

of energy used and is measured in kilowatt hours (kWh's) over the billing period. The charge is

calculated based on the current rate of the tariff schedule of the facility.

Electrical demand (kW) can amount to as much as 50 percent or more of the total electricity bill.

It is often possible to significantly decrease the electric bill by reducing the demand, while still

using the same amount of energy to perform the desired work. There is no charge for the first

50kW of demand, however if the maximum level of demand exceeds 50kW, there will be a charge

for both the energy and the demand.

The other major components of the electric bill are the delivery charges, regulatory charges, debt

retirement charge, and the HST sales taxes.

4.1- WATER TREATMENT PLANT & WATER PUMP STATIONS

4.1.1- WATER TREATMENT PLANT

Figure 2-1 and 2-2 illustrate the monthly energy consumption and electrical demand for the

period 2010 to 2012. From these charts, it can be determined that the electrical baseline

consumption averages around 120,000 kWh / month, with consumption increasing during the

summer months as a result of higher demand in this season. The highest peak demand has been

453 kW reached on July 2012. The demand trend is also seasonal with higher levels of kW

demand during the summer months.

This facility is billed using a Weighted Average Price kWh charge based on the consumption

pattern of the distribution company (Innisfil Hydro) in conjunction with a Global Adjustment

price charge. Demand charges for the plant are calculated based on the highest demand usage for

the monthly billing period.


Table 3 below illustrates the electrical energy use breakdown by major end use equipment type.

End-Use Number of

Machines kW Operation % of Total

Low lift Pump (LLP) 3 100 hp

On VFD; one pump

operating; two when

high demand

28%

High lift Pump (HLP) 4 125 hp

One pump operating;

two when high

demand

34%

Figure 2-1: WTP Electrical Usage

Figure 2-2: WTP Electrical Demand


Backwash Pump 2 150 hp

One pump operating

once every 42 hours

for 7 to 13 minutes

21%

Blower 2 40 hp

One pump operating

once every 72 hours

for each filter +

backwash operation

5%

GSC System 3 50 hp One pump operating;

summer period 6%

Backwash pumps 2 20 hp One pump operating 3%

Underflow pumps 2 7.5 hp Two pumps operating 1%

Lighting (Fluorescent, Metal

Halides and High Discharge

Lamps

85+

70-175-

400

watts

Operating when

Infrequent operation

inside the plant

2%

Table 3- WTP Equipment List

4.1.2- ZONE 2 BOOSTER STATION



consumption averages around 9,000 kWh / month, with the higher consumption levels occurring

during the first quarter of the year. The highest peak demand has been 30 kW reached on June

2010 with an average demand of 20 kW.

This facility is billed using a Time of Use (TOU) Price kWh charge where the price of electricity

depends on when it is used. Delivery charges are calculated according to the rate schedule

General Service ˂50kW and account for delivering electricity from the generating stations to

Innisfil Hydro distribution networks and then to the facility.


Table 4 illustrates the electrical energy use breakdown by major end use equipment type.

End-Use Number of


Max Duty HP60 1 60 hp

Operating for

emergency and fire

only

--

High lift Pump (HLP 2 &3) 2 50 hp

On VFD; currently not

running; planned for

new development

--

High lift Pump (HLP 2 &3) 1 20 hp On VFD; continuous

operation 80%

Electric Heaters and Lighting 2 5 kW Continuous operation

in winter 20%

Table 4- Zone 2 Booster Equipment List

Figure 2-3: Z2 Booster Electrical Usage

Figure 2-4: Z2 Booster Electrical Demand


4.1.3- STROUD WATER STATION



consumption averages around 30,000 kWh / month, with the higher consumption levels

occurring during the first quarter of the year. The highest peak demand has been 133 kW

reached on May 2011; however the station has an average demand of 100 kW.

This facility is billed using a Regulated Price Plan (RPP) Price kWh charge under which

consumers pay tiered prices reviewed by the Ontario energy Board (OEB) twice a year. Demand

and delivery charges for the plant are calculated based on the highest demand usage for the

monthly billing period.

Figure 2-5: Stroud Electrical Usage

Figure 2-6: Stroud Electrical Demand



End-Use Number of


Fire Pump 1 75 hp

Operating for

emergency and fire;

operates when high

demand or backwash

operation

--

High lift Pump (HLP) 3 15 hp One operating; two

when high demand 40%

Submersible Well Pumps 3

2.25 hp

15 hp

30 hp

30 hp pump

operating 40%

Electric Heaters and Lighting 4 5 kW Continuous operation

in winter 20%

Table 5- Stroud Water Station Equipment List

4.1.4- MURF STATION




during the first quarter of the year. The highest peak demand has been 26 kW reached on June

2011; however the facility has an average demand of 20 kW.







End-Use Number of


Emergency/Fire Pump HP3 1 50 hp

Operating for

emergency and fire

only

--

High lift Pump (HLP) 2 20 hp

On VFD; one pump

operating; two pumps

when high demand

88%

Sewage Pumps 2 4.8 kW

One pump running;

one to two hours per

day

8%

Electric Heaters and Lighting -- 2 kW Continuous operation

in winter 4%

Table 6- MURF Station Equipment List

Figure 2-7: MURF Electrical Usage

Figure 2-8: MURF Electrical Demand


4.1.5- LAKESHORE RESERVOIR BOOSTER STATION




during the first quarter of the year. The highest peak demand has been 29 kW reached on

February 2011; however the facility has an average demand of 25 kW.





Figure 2-9: Lakeshore ST Electrical Usage

Figure 2-10: Lakeshore ST Electrical Demand



End-Use Number of


Pumps to the IRC 2 15 hp

One pump operating;

2-3 hours/day

Off peak hours

irrigation

85%


in winter 15%

Table 7- Lakeshore Reservoir Equipment List

4.1.6- THIRD LINE BOOSTER STATION




summer months as a result of higher demand in this season. The highest peak demand has been

114 kW reached on February 2012 while average demand ranges from 60 kW to 100 kW.





Figure 2-11: 3rd Line Booster Electrical Usage



End-Use Number of


High Lift Pump (HLP) 2 150 hp Not running --

High Lift Pump (HLP) 2 50 hp

One pump running;

two pumps operating

when high demand

80%


in winter 20%

Table 8- Third Line Booster Equipment List

Figure 2-12: 3rd Line Booster Electrical Demand


4.2- WASTEWATER FACILITIES

4.2.1- LAKESHORE WASTEWATER PLANT



consumption averages around 260,000 kWh / month. The highest peak demand has been 448

kW reached on January 2011 while average demand ranges from 360 kW to 400 kW.





Figure 3-1: Lakeshore Wastewater Electrical Usage

Figure 3-2: Lakeshore Wastewater Electrical Demand



End-Use Number of


Air Blower 3 125 hp

One Blower operating

at a time; Eff. 93.6%

Intake control valves

not operating

30%

Screw Lift Pump 4 15 hp

Two pumps

operating; four in

winter

6%

Blowers for Storage Tanks 2 125 hp One Blower operating

at a time 30%

Blowers for preliminary Tanks 2 75 hp One Blower operating

at a time 18%

Treatment Facility

Rejection Pumps 2 10 hp 2%

Effluent Pumps 3 15 hp One pump operating

at a time 3%

Twin Compressor for treatment

air lift 2 25 hp 8%

Lighting and other equipment 3%

Table 9- Lakeshore wastewater Plant Equipment List


4.2.2- COOKSTOWN WASTEWATER PLANT




winter months. The highest peak demand has been 79 kW reached on April 2012 while average

demand ranges from 40 kW to 60 kW.

Figure 3-3: Cookstown Wastewater Electrical Usage

Figure 3-4: Lakeshore Wastewater Electrical Demand



End-Use Number of


Air Blower 4 7.5 hp

- Two Blowers

operating 24/7

- Operating on VFDs

7%

Sewage Pump 2 35 hp 30%

Effluent Pump 2 5 hp One pump operating

at a time 4%

Effluent Pump 2 60hp

- One pump operating

at a time

- operating in fall and

spring

52%

Sludge transfer pump --

Heaters and lighting 5 kW 6%

Table10- Cookstown Wastewater Equipment List

4.2.3- SEWAGE STATION 1




winter months. The highest peak demand has been 69 kW reached on May 2011 while average

demand ranges from 30 kW to 50 kW.



End-Use Number of


Sewage Pump 2 100 hp


at a time

- Operating on VFDs

80%

Electric Heaters and Lighting - 25 kW Continuous operation

in winter 20%

Table 11- Sewage Station 1 Equipment List

Figure 3-5: Sewage Station 1 Electrical Usage

Figure 3-6: Sewage Station 1 Electrical Demand





consumption averages around 1,000 kWh / month, with consumption increasing to an average of

1,700 kWh during the winter months. The highest peak demand has been 13 kW reached on July

2012 while average demand ranges from 8 kW to 10 kW.


End-Use Number of


Submersible Pump 2 7.5 kW - One pump operating

at a time 95%

Lighting - 5%








consumption averages around 30,000 kWh / month, with consumption increasing to an average

of 35,000 kWh during the winter months. The highest peak demand has been 151 kW reached on

November 2011 while average demand ranges from 70 kW to 80 kW.





End-Use Number of


Sewage Pump 3 100 hp


at a time

- Two pumps

operating on VFD, the

third is constant

speed

80%


in winter 20%





consumption averages around 14,000 kWh / month, with consumption increasing to an average

of 19,000 kWh during the winter months. The highest peak demand has been 58 kW reached on

March 2011 while average demand ranges from 35 kW to 50 kW.




End-Use Number of


Sewage Pump 3 50 hp


at a time

- Two pumps

operating on VFD, the

third is constant

speed

70%


in winter 30%



Figure 3-13 illustrates the monthly energy consumption for the period 2010 to 2012. From this

chart, it can be determined that the electrical baseline consumption averages around 1,000

kWh/month, with consumption increasing to an average of 2,000 kWh during the winter months.

There is no billing information on the electrical demand for this facility.




End-Use Number of


Submersible Pump 2 7.5 hp - One pump operating

at a time 60%

Lighting - 5 kW Operating in winter 40%



Figure 3-14 illustrates the monthly energy consumption for the period 2010 to 2012. From this

chart, it can be determined that the electrical baseline consumption averages around 250 kWh /

month, with consumption increasing to an average of 330 kWh during the winter months. There

is no billing information on the electrical demand for this facility.




End-Use Number of


Sewage Pumps 2 4.8 kW

One pump running;

one to two hours per

day

100%



4.3.1- INNISFIL RECREATIONAL CENTRE



consumption averages around 400,000 kWh / month. The highest peak demand has been 876

kW reached on August 2011 while average demand ranges from 700 kW to 800 kW.








End-Use Number of


Refrigeration Plant

Screw-type Compressor 3 75 hp Peak need between

4pm and 23pm

40%

Glycol Floor Pump 3 --

Building Heat System Pumps 2 50 hp

Condenser Pump 1 15 hp One pump operating;

on VFD

Under-floor Heat Pump 1 5 hp

Glycol Supply Building Pump 1 15 hp

Figure 4-1: IRC Electrical Usage

Figure 4-2: IRC Electrical Demand


Cooling Tower and Rooftop Equipment

Fan 2 50 hp 2-speed motor

(50/12.5 hp) 5%

Spray Pump 1 7.5 hp

Dehumidifier DU1 - 20 hp 4%

Dehumidifier DU1 - 13 hp

Boiler Room

Hot Water Supply Pump 2 10 hp 4%

Water/Glycol Pump 17 1 hp

Mechanical Room

Dectron AHU

Compressor 2 50 hp

12% Blower Motor 1 25 hp

Blower Motor 1 7.5 hp

McQuay HP1

Compressor 1 1 10 hp

3% Compressor 2 1 15 hp

Fan 1 4 hp

McQuay HP2



Fan 1 4 hp

McQuay HP3



Fan 1 4 hp

McQuay HP4

Compressor 1 10 hp 1%

Fan 1 3 hp

Unit HRU1

Compressor 1 1 6.7 hp

4%


Condenser Fan 2 1 hp

Evaporator Fan 1 10

Return/Exhaust Fan 1 7.5


Unit MU1

Supply Fan 1 4.76 Runs on VFD

Pool Mechanical Room

Circulation Pumps 1 22 hp

5%

Hydrotherapy Pump 1 7.5 hp

Umbrella Pump 1 7.5 hp

Water Tunnel 1 1 hp

Pool Filter 1 15 hp

Lighting (only lighting eligible for retrofit is considered in this table)

Ice Rink #2 46 175

watts Metal halide Lamps

Table 17- IRC Equipment List

4.3.2- STROUD ARENA



consumption averages around 100,000 kWh / month with higher consumption level in non-

summer months. The highest peak demand has been 283kW reached on January 2011 while

average demand ranges from 100 kW to 200 kW.





Figure 4-3: Stroud Arena Electrical Usage



End-Use Number of


Refrigeration Plant

Arena Compressor 2 50 hp

60%

Curling Club Compressor 1 50 hp

Ammonia Pump - 25 hp

Calcium Chloride Pump 1 15 hp

Condenser water Supply 1 7.5 hp

Compressor Cooling Glycol 1 1 hp

Cooling Tower Condenser Fan 1 15 hp Not running on VFD

AC Units

Central Cooling AC

Compressor 2 15 hp

8% ID Blower 1 7.5 hp

OD Fan 2 1.25 hp

Central AC Arena (2 units)

Compressor 2 7.5 hp 5%

Fan 2 0.25 hp

Central AC Curling (1 unit)

Compressor 1 10 hp 4%

Fan 1 0.25 hp

Figure 4-4: Stroud Arena Electrical Demand



Ice Rink

Metal Halides Lamp 24 1000 w

Curling Club


Table 18- Stroud Arena Equipment List

4.3.3- LEFROY ARENA



consumption averages around 50,000 kWh / month with higher consumption level in non-

summer months. The highest peak demand has been 174 kW reached on December 2011 while

average demand ranges from 50 kW to 150 kW.





Figure 4-5: Lefroy Arena Electrical Usage



Table 19- Lefroy Arena Equipment List

End-Use Number of


Refrigeration Plant

Reciprocating Compressor 2 50 hp

65% Condenser water Supply 1 3 hp

Cooling Brine Supply 1 20 hp

AC Unit

Central Cooling AC

Compressor - Blower 1 30 hp 18%

Dehumidifier

Motor 1.5 hp

2% Motor 1/3 hp

Heater - 400 w


Ice Rink


Figure 4-6: Lefroy Arena Electrical Demand


5- IDENTIFIED CONSERVATION PROJECTS AND

RECOMMENDATIONS

5.1- WATER TREATMENT PLANT AND PUMP STATIONS

5.1.1- OFF-PEAK PUMPING CAPABILITY

As part of the energy assessment initiative, the REM assessed the viability of off-peak pumping at

the Water Treatment Plant in an effort to take advantage of the reduced electricity rates during

off-peak hours. To undertake this evaluation, the REM performed an evaluation of the existing

demands to determine the feasibility for shifting pumping during the peak day period to off-peak

hours.

Data from the SCADA system shows that the High-Lift pumps operate over a range of 14 hours to

18 hours daily during non-summer months with only one pump running at a time, and up to 24

hours/day for the months of July and August.

The main reservoir system, the Alcona Reservoir, has a capacity of 8,700 m3 with the following

equalization volumes:

Equalization storage volume: 3,505 m3

Fire storage volume: 3,455 m3

Emergency storage volume: 1,740 m3

The High Lift pumps (HLPs) are four equally sized 125 hp high lift turbine pumps placed over the

wells and pump treated water to the distribution system and/or the Reservoir. The maximum

hourly flow per pump from the Water Treatment Plant is 537m3/h.

The evaluation was run with one HLP pumping at full capacity starting at 00 AM until the top of

the Reservoir level is met. One HLP can supply the tank an amount equal to the difference

between the total hourly production rate and the hourly system demand. During off-peak hours,

the Reservoir fills, since the off-peak demand is most likely less than the total supply of one HLP.


Currently, this facility is billed using a Weighted Average Price kWh charge based on the

consumption pattern of the distribution company (Innisfil Hydro) in conjunction with a Global

Adjustment price charge.

For energy cost savings from shifting consumption to off-peak hours to be recognized, the WTP

should acquire an interval meter under which billing would take into account the time of the day

where energy is consumed and the corresponding electricity price for each interval period.

The value in cost savings from utilizing the off-peak pumping of the WTP is estimated to amount

to $5,000/year.

5.1.2- DEMAND CURTAILMENT

There is an opportunity for the WTP and the Stroud Water Station to participate in the provincial

Demand Response DR3 program offered in Ontario. Demand Response can be met by shedding

load by turning off lights or motors, shifting production to other periods, or drawing electricity

supply from an onsite generator. Combined with the possibility to shift pumping to off-peak

hours, the LLP’s and HLP’s at the WTP and the Fire Pump at the Stroud Water Station are major

candidates to allow participating in this program.

The two facilities must be available approximately 1,600 hours/year and must select to

participate in one of two of the pre-defined schedules: from 12 p.m. to 9 p.m. on business days for

all summer months, and from 4 p.m. to 9 p.m. on business days for all non-summer months; or

from 12 p.m. to 6 p.m. on business days for all months.

Each activation period will be for four consecutive hours, and through a year will total either up

to 100 hours or 200 hours as specified in the contract with the Demand Response Provider.

Activation notices are issued by the Independent Electricity System Operator (IESO) to the

Demand Response Provider when there is a system need.

The Facilities will receive “capacity” payments for each hour of the 1600 hours, plus additional

“energy” payments for the actual amount of energy curtailed during an event.


Participating in this initiative will yield 200 kW and 50 kW in Demand curtailment at the WTP

and the Stroud Water Station respectively, and the value of financial compensation from

participating in the DR3 program is estimated to be $25,600/year for the WTP and $5,600 for the

Stroud Water Station.

5.1.3- VARIABLE FREQUENCY DRIVES

The Low Lift pump station houses the raw water intake channels, screening equipment and three

(3) 100hp low lift turbine pumps controlled by three variable frequency drives.

The high lift pumps in the WTP operate for an average daily time between 14 hours and 18

hours. There is opportunity to spread the HLP maximum flow (150 L/s) to operate the pump

over 24 hours a day using variable frequency drives to adjust the flow rate requirements to an

average of 125 L/s. Further investigation must be carried out to verify head and pressure

requirements. The VFD could also be used to show flow, pressure, efficiency, cavitation and other

pump curve specific parameters, either locally or on the SCADA system.

The value in cost savings from utilizing variable frequency drives on the high lift pumps in the

WTP is estimated to amount to $10,000/year.

5.1.3- BACKWASH PUMPS OPERATION

The filters in the WTP are cleaned regularly, typically every 36 hours of filter running time.

Compressed air is used to expand the bed in conjunction with the filter taken from the clear

wells. The filter water is pumped at a high flow rate by one of the two backwash pumps vertically

through the filter to flush out the sediment and direct it to the backwash tanks. According to the

data collected from the WTP 2012 daily reports, the backwash operation time ranges from 4.8

minutes to 13 minutes per cycle with and average running time of 7 minutes. Demand billing is

based on a rolling 15-minute kW derived quantities that are calculated from 5-minute sub-

intervals over a rolling period of 15 minutes. These derived quantities are calculated at the end of

each 5-minute sub-interval based on the kWh consumed during the rolling 15-minute period.


There is opportunity to investigate, including with the filters manufacturer, the possibility of

operating the backwash pumps for periods not exceeding 5 minutes in duration. This initiative

will allow the WTP aggregated billed demand to not include the demand level caused by the

backwash pumps operation.

The value in cost savings from utilizing the off-peak pumping of the WTP is estimated to amount

to more than $5,000/year while reducing the monthly billed demand by at least 40 kW.

5.2- WASTEWATER TREATMENT FACILITIES

5.2.1- VARIABLE FREQUENCY DRIVES ON AERATION TANK BLOWERS

The blowers for supplying air to the aeration system are housed in the building located directly

adjacent to the four aeration tanks. Three, 125 hp centrifugal blowers are installed and their

operation is such that the projected dissolved oxygen (DO) demand can be met with one unit in

service.

The facility operator has indicated that only one of the three duty blowers is operated a time to

aerate the nitrification tanks. The facility was originally designed to throttle the inlet valves on

the blowers to decrease the amount of air that is delivered to the aeration tanks.

Based on information taken at the site visit, it is estimated that one blower operates all the time,

translating into a yearly energy cost of $82,000.

The malfunction of the inlet valves on the blower intake lines indicate that too much oxygen is

being delivered resulting in high DO concentrations in the nitrification tanks.

One option to modify the existing blowers would be to install variable speed drives (VFDs) to

control the speed of the motors, with dissolved oxygen sensors and controllers provided for each

aeration tank.

The value in cost savings from utilizing variable frequency drives on the aeration tank blowers is

estimated to amount to $20,000/year.



5.3.1- VARIABLE FREQUENCY DRIVES

IRC: The IRC’s Mechanical Room houses seven air handling units. There is an energy saving

opportunity to install VFD’s on the 25 HP and 7.5 HP blowers of the Dectron unit and on the

Return/Exhaust Fan of the HRU1 unit.

The combined value in cost savings from utilizing variable frequency drives on these fans is

estimated to amount to $1,800/year with an average simple payback period of 3 years.

There is also an energy saving opportunity to install a VFD on the 7.5 HP condenser water supply

pump of the refrigeration plant at the Stroud Arena, and a VFD on the cooling tower’s 15 HP

condenser fan.

The combined value in cost savings from utilizing variable frequency drives on these fans is

estimated to amount to $900/year with a combined simple payback period of 3.6 years.

5.3.2- LIGHTING

IRC: The IRC race track lighting in ice rink#2 is provided by (46) 175-watt metal halide lamps

operating 12 hours a day through the week and 18 hours a day on weekends.

There is an energy saving opportunity to replace these lamps with (46) 4-lamp 25-watt T5

fixtures resulting in 3.7 kW in demand reduction and 20,000 kWh in usage decrease.

The value in cost savings from replacing the metal halide lamps with 4-lamp 25-watt T5 fixtures

is estimated to amount to $2,000/year with a simple payback period of 2 years.

Stroud Arena: The ice rink lighting in the Stroud Arena is provided by (24) 1000-watt metal

halide lamps operating for an average of 6 hours a day throughout the year.

There is an energy saving opportunity to replace these lamps with (48) 4-lamp 54-watt T5HO


The value in cost savings from replacing the metal halide lamps with 4-lamp 54-watt T5HO

fixtures is estimated to amount to $2,500/year with a simple payback period of 2.4 years.


The lighting in the curling club is provided by (45) 400-watt metal halide lamps operating for an

average of 6 hours a day throughout the year.





Lefroy Arena: The ice rink lighting in the Lefroy Arena is provided by (50) 400-watt metal halide

lamps operating for an average of 6 hours a day throughout the year.





6- AVAILABLE INCENTIVES AND FUNDING SOURCES

6.1- DEMAND RESPONSE DR3 PROGRAM

The Demand Response programs compensate participating industrial and commercial

businesses for reducing their energy demand at specific times of power system need. During

such times wholesale market prices for electricity may be high, the power system is experiencing

large peaks in demand, or there is a greater risk to the reliability of the electricity grid.

Under the DEMAND RESPONSE DR3 (DR3) program, the participant agrees to make a firm

commitment to reduce its energy use during periods of peak demand. In exchange, the

participant will get an increased incentive rate.

To be eligible, the participant must be operating and available during a predefined schedule of

about 1,600 hours per calendar year. Within that 1,600-hour period, the participant can select to

participate in potential activations of up to either 100 hours or 200 hours per year.

The participant will receive “capacity” payments for each hour of the 1600 hours, plus additional

“energy” payments for the actual amount of energy curtailed during an event.


Performance in DEMAND RESPONSE DR3 is assessed by comparing the actual metered load

during an activation period with a calculated baseline representing what the normal load would

have otherwise been during the activation period.

Participants must be available approximately 1,600 hours/year and must have selected to

participate in one of two of the pre-defined schedules: from 12 p.m. to 9 p.m. on business days for

all summer months, and from 4 p.m. to 9 p.m. on business days for all non-summer months; or

from 12 p.m. to 6 p.m. on business days for all months.

Each activation period will be for four consecutive hours, and through a year will total either up

to 100 hours or 200 hours as specified in the contract between the participant and the Demand

Response Provider. Activation notices are issued by the Independent Electricity System Operator

(IESO) to the Demand Response Provider when there is a system need.

There is an opportunity for the WTP and the Stroud Water Station to participate in the DR3

program. The LLP’s and HLP’s at the WTP and the Fire Pump at the Stroud Water Station are

major candidates to allow participating in this program. At the WTP and Reservoir, the

equalization storage capacity (3,505m3) is sufficient to provide water to the distribution system

for at least 7 hours. While the water in the reservoir level is continuously maintained at its

maximum level, this capacity will allow the WTP to respond to any 4-hour activation without

limiting the water supply requirements in the distribution system.

Equipment

providing DR Peak kW Load

Potential

Average kW

Load during

DR Event

Average kW of

DR Potential

Potential

number of

continuous

hours

available for

providing DR

Restrictions

with

providing DR

WTP

HLPs and LLPs 450 kW 200 kW 335 kW 5,500/year

Water Demand

and Reservoir

Capacity

Stroud Water

Fire Pump 100 kW 55 kW 55 kW 2,000/year

High Demand

and Emergency

Service


6.2- RETROFIT PROGRAM

The RETROFIT PROGRAM provides substantial financial incentives for replacing existing

equipment with high efficiency equipment and for installing new control systems that

will improve the efficiency of operational procedures and processes.

Lighting retrofits, lighting controls and variable speed drives are some of the eligible measures

under this program.

There are three ways to start conserving energy with this program:

1. PRESCRIPTIVE Track

2. ENGINEERED Track

3. CUSTOM Track

All of the retrofit measures recommended in this report have been calculated using the

prescriptive or engineered sheet tracks to generate the maximum incentive amounts.


7- APPENDICES

7.1- HISTORICAL DATA ANALYSIS

Water Treatment Plant

2012 2011 2010

kWh kW $ kWh kW $ kWh kW $

Jan 87,042.60 241.20 $5,970.34 85,108.00 233.00 $5,361.52 98,004.00 272.00 $6,995.47

Feb 93,490.20 243.00 $6,691.75 116,702.00 239.00 $8,455.12 77,371.00 244.00 $5,276.41

Mar 106,385.40 261.60 $7,026.44 90,911.00 242.00 $6,257.59 88,332.00 401.00 $5,618.37

Apr 90,266.40 253.80 $8,291.78 93,490.00 274.00 $6,442.64 92,201.00 245.00 $5,979.24

May 105,095.88 268.20 $7,962.79 89,621.64 247.00 $6,292.51 78,661.00 237.00 $5,884.62

June 134,754.84 444.00 $10,272.27 97,358.76 255.00 $8,006.30 104,451.00 368.00 $7,304.07

July 156,031.92 424.80 $13,551.35 139,268.16 453.00 $10,713.42 110,899.00 323.00 $8,290.01

Aug 139,268.16 311.40 $9,559.24 99,937.80 255.00 $6,160.57 98,648.00 250.00 $6,805.44

Sept 105,740.60 393.00 $6,800.39 101,872.08 249.00 $7,720.47 99,938.00 246.00 $4,746.09

Oct 94,134.96 268.00 $6,470.32 81,885.00 315.00 $4,464.45

Nov 87,042.60 238.80 $5,801.91 77,371.00 307.00 $5,174.81

Dec 105,740.64 239.40 $7,690.37 98,648.00 235.00 $6,967.14

Total 1,018,076.00 76,126.35 1,201,187.64 85,372.74 1,106,409.00 73,506.12

Av. & Max 113,119.56 444.00 8,458.48 100,098.97 453.00 7,114.40 92,200.75 401.00 6,125.51

Zone 2 Booster Station

2012 2011 2010


Jan 11,992.54 10.56 $986.38 13,540.00 20 $994.45 12,637.00 24 $12,637.00

Feb 11,476.79 $943.57 15,990.00 22 $1,175.76 10,703.00 22 $10,703.00

Mar 12,121.49 $997.08 10,961.00 20 $803.60 10,961.00 22 $10,961.00

Apr 8,243.51 $611.46 9,800.00 21 $717.72 7,479.00 21 $7,479.00

May 5,416.89 $431.44 8,252.93 18 $643.73 5,803.00 21 $5,803.00

June 4,916.55 $390.90 9,542.45 18 $745.60 4,900.00 30 $4,900.00

July 5,013.92 $397.11 6,963.41 18 $541.86 5,287.00 18 $5,287.00

Aug 4,774.80 $380.71 6,060.74 12 $470.54 4,900.00 19 $4,900.00

Sept 4,644.34 $361.60 6,705.50 13 $521.48 5,287.00 19 $5,287.00

Oct 6,189.70 15 $482.33 5,287.00 28 $5,287.00

Nov 6,963.41 26.04 $568.96 5,674.00 20 $5,674.00

Dec 9,413.50 26.88 $772.32 7,350.00 23 $7,350.00

Total 68,600.83 5,500.25 110,382.64 8,438.35 86,268.00 86,268.00

Av. & Max 7,622.31 10.56 611.14 9,198.55 26.88 703.20 7,189.00 30.00 7,189.00


Stroud Water Station

2012 2011 2010


Jan 27595.73 99.36 $2,281.44 44875 91 $3,313.27 25275 69 $1,714.22

Feb 30948.48 99.36 $2,559.72 26822 60 $1,765.58

Mar 27079.92 92.88 $2,238.63 37396 99 $2,759.81 25275 60 $1,513.83

Apr 25532.5 95.04 $2,114.43 35591 95 $2,626.21 25275 86 $1,939.05

May 28111.54 99.36 $2,464.06 31722.19 133.92 $2,497.80 26048 56 $1,946.13

June 23469.26 90.72 $2,055.54 25532.5 108.00 $2,008.81 24501 54 $1,830.07

July 26,048.30 101.52 $2,282.50 31722.19 108.00 $2,497.80 26564 52 $1,984.81

Aug 24,500.88 95.04 $2,146.33 25016.69 95.04 $1,968.06 24243 123 $1,810.73

Sept 18,569.09 90.72 $1,624.33 27337.82 99.36 $2,151.43 19859 60 $1,481.90

Oct 27854 20374 66 $1,513.78

Nov 27337.82 99.36 $2,260.04 38686 69 $2,855.23

Dec 33527.52 97.20 $2,773.78 37654 65 $2,778.89

Total 231,855.70 19,766.98 347,912.73 24,857.01 320,576.00 23,134.22

Av. & Max 25,761.74 101.52 2,196.33 31,628.43 133.92 2,485.70 26,714.67 123.00 1,927.85

MURF Station

2012 2011 2010


Jan 9542.45 21.72 $783.02 10574 22 $774.98 10316 22 $684.43

Feb 8897.69 $729.51 14314 22 $1,051.71 10445 21 $693.07

Mar 8768.74 $718.80 10961 22 $803.60 10316 25 $684.43

Apr 7774.26 $582.32 9542 23 $698.94 8382 22 $581.35

May 6986.75 $567.81 7221.31 26 $562.23 8253 20 $611.47

June 6425.55 $513.37 6189.7 26 $480.73 6319 19 $466.40

July 6936.21 $554.73 8123.98 19 $633.54 6963 23 $514.76

Aug 6703.7 $537.82 6963.41 24 $541.86 7092 22 $524.43

Sept 6617.43 $524.86 7350.26 20 $572.42 6577 21 $485.75

Oct 6060.74 24 $472.90 8511 24 $627.40

Nov 3223.8 18.72 $568.96 9929 24 $727.27

Dec 8510.83 19.68 $697.40

Total 68,652.78 5,512.24 99,035.03 7,859.27 93,103.00 6,600.76

Av. & Max 7,628.09 21.72 612.47 8,252.92 26.00 654.94 8,463.91 25.00 600.07


Lakeshore Reservoir Booster

2012 2011 2010


Jan 8,935.30 $732.63 9,058.00 27 $662.78 9,463.00 26 $627.27

Feb 10,161.42 $834.40 11,453.00 29 $840.03 8,663.00 26 $573.70

Mar 10,425.77

$856.34 9,236.00 26 $675.97 9,079.00 26 $601.56

Apr 9,659.76 $720.77 8,087.00 23 $590.97 8,655.00 24 $573.13

May 8,457.45 $684.50 5,530.97 22.81 $428.70 6,715.00 23 $464.37

June 6,817.60 $541.84 3,901.87 $300.00 3,727.00 21 $272.01

July 1,767.40 $139.76 2,116.96 $158.99 1,484.00 13 $103.80

Aug 1,572.20 $121.89 1,835.42 $136.75 1,657.00 12 $116.78

Sept 1,678.25 $130.73 1,476.50 $108.39 1,932.00 13 $137.41

Oct 1,946.10 $145.49 1,852.00 15 $131.37

Nov 6,646.40 $542.65 2,039.00 23 $144.58

Dec 7,958.49 $651.55 7,698.00 25 $562.18

Total 59,475.15 4,762.86 69,246.71 5,242.27 62,964.00 4,308.16

Av. & Max 6,608.35 0.00 529.21 5,253.97 29.00 425.68 5,247.00 26.00 359.01

Third Line Booster

2012 2011 2010


Jan 28369.44 114.24 $1,974.77 29143 60 $1,809.12 23727 83 $1,620.66

Feb 28111.54 114.24 $2,012.13 28627 60 $2,120.69 25533 59 $1,772.66

Mar 30948.48 58.56 $2,019.01 24759 63 $1,706.69 21922 59 $1,272.68

Apr 24242.98 57.36 $2,227.09 25790 57 $1,773.48 22953 56 $1,657.10

May 29401.06 86.16 $2,227.63 23469.26 53 $1,654.47 23211 50 $1,745.80

June 29143.15 46.32 $2,224.81 30948.48 64.00 $2,505.08 25017 48 $1,607.71

July 30690.52 103.92 $2,672.72 29401.06 87.00 $2,278.61 22180 107 $1,771.77

Aug 33011.71 82.08 $2,264.13 22179.74 59.00 $1,374.65 20117 45 $1,162.20

Sept 27853.63 82.32 $1,791.33 29916.86 59.00 $2,256.96 19859 46 $979.77

Oct 27079.92 59.00 $1,858.22 19601 48 $1,125.63

Nov 27079.92 63.60 $1,811.10 21664 50 $1,535.93

Dec 32238 111.60 $2,318.45 23211 56 $1,609.32

Total 261,772.51 19,413.62 330,632.24 23,467.52 268,995.00 17,861.23

Av. & Max 29,085.83 114.24 2,157.07 27,552.69 111.60 1,955.63 22,416.25 107.00 1,488.44


Lakeshore Water Pollution Control Plant

2012 2011 2010


Jan 280714.35 411.3 269837 448 288675 404

Feb 264922.32 403.65 237579 388 261036 426

Mar 262689.56 398.93 261753 391 275399 398

Apr 261879.1 383.18 248876 389 264637 407

May 259214.7 374.18 265114.4 386 264883 395

June 243170.45 362.48 244834.6 371.00 256395 382

July 248807.7 356.85 248427.8 357.00 259458 370

Aug 257,484.63 371.70 255004.1 379.00 262163 372

Sept 244,397.60 362.03 244845.4 366.00 233531 362

Oct 265712.6 386.00 249545 370

Nov 272857.8 412.43 259272 392

Dec 278076.2 391.05 267366 377

Total 2,323,280.41 3,092,917.90 3,142,360.00

Av. & Max 258,142.27 411.30 257,743.16 448.00 261,863.33 426.00

Cookstown Water Pollution Control Plant

2012 2011 2010


Jan 21663.94 45.6 29143 48 19343 48

Feb 21148.13 43.2 22180 58 20117 48

Mar 21663.94 76.8 20890 62

Apr 20116.51 79.2 32496 77 14185 72

May 14700.53 40.8 23211.36 33.72 14185 38

June 15216.34 28.8 14184.72 33.60 13153 29

July 13153.1 36.00 14184.72 43.20 14443 34

Aug 16,247.95 33.60 12379.39 48.00 12121 29

Sept 12,637.30 33.60 14442.62 36.00 12379 38

Oct 15990.05 62.40 15732 48

Nov 19084.9 62.40 18053 43

Dec 24242.98 45.60 27854 48

Total 156,547.74 221,539.74 202,455.00

Av. & Max 17,394.19 79.20 20,139.98 77.00 16,871.25 72.00


Sewage Pump Station 1

2012 2011 2010


Jan 13668.91 30.24 15474 24 13411 13

Feb 13153.1 30.24 16506 24 12121 30

Mar 14700.53 30.24 15216 24 11864 26

Apr 10058.26 30.24 12637 24 8511 22

May 6963.41 30.24 8768.74 69.12 7221

June 6189.7 43.2 5415.98 17.28 6448

July 5,158.08 51.84 6447.6 17.28 6963

Aug 7,479.22 47.52 5673.89 69.12 6706

Sept 4,384.37 49.68 5158.08 19.44 4384

Oct 6189.7 62.64 5674

Nov 9284.54 43.20 8511

Dec 15216.34 28.08 14185

Total 81,755.58 121,987.87 105,999.00

Av. & Max 9,083.95 51.84 10,165.66 69.12 8,833.25 30.00


2012 2011 2010


Jan 1805.33 8.64 2837 14 1805 5

Feb 1547.42 8.64 2321 10 1547 10

Mar 1289.52 10.8 2063 10 1290 10

Apr 1289.52 10.8 1290 8 1032 10

May 515.81 10.8 773.71 8.64 516 10

June 515.81 4.32 515.81 8.64 516 10

July 515.81 12.96 1031.62 8.64 774 10

Aug 773.71 10.80 515.81 8.64 516 10

Sept 515.81 4.32 773.71 12.96 258 17

Oct 773.71 17.28 774 10

Nov 773.71 8.64 774 12

Dec 1805.33 8.64 1547 9

Total 8,768.74 15,474.41 11,349.00

Av. & Max 974.30 12.96 1,289.53 17.28 945.75 17.00



2012 2011 2010


Jan 32238 77.76 33528 95 27338 78

Feb 29143.15 82.08 34301 82 22953 60

Mar 36364.46 79.92 36107 86 29569 130

Apr 27079.92 82.08 37138 125 26822 69

May 22953.46 79.92 28885.25 86.4 24243 130

June 22179.74 79.92 17795.38 60.48 23727 65

July 20,116.51 64.80 21921.84 56.16 22696 86

Aug 25,016.96 79.92 20116.51 69.12 22696 69

Sept 18,569.09 58.32 19342.8 60.48 17022 48

Oct 21921.84 95.04 17537 56

Nov 23727.17 151.20 22438 65

Dec 37396.08 86.40 25017 69

Total 233,661.29 332,180.87 0.00 282,058.00

Av. & Max 25,962.37 82.08 27,681.74 151.20 #DIV/0! 23,504.83 130.00


2012 2011 2010


Jan 14184.72 43.2 18311 48 19085 48

Feb 15216.34 47.52 20117 48 15216 43

Mar 17021.66 47.52 18053 58 14958 52

Apr 12637.3 36.72 17022 42 18053 48

May 9542.45 51.84 14184.72 47.52 13411 58

June 9542.45 43.2 9542.45 43.20 10832 38

July 9,542.45 32.40 6705.5 34.56 10058 43

Aug 10,574.06 36.72 9026.64 47.52 8511 38

Sept 7,479.22 23.76 7995.02 25.92 8253 36

Oct 9542.45 49.68 9285 48

Nov 12637.3 56.16 9285 43

Dec 18826.99 56.16 14701 50

Total 105,740.65 161,964.07 151,648.00

Av. & Max 11,748.96 51.84 13,497.01 58.00 12,637.33 58.00



2012 2011 2010


Jan 2107.29 3171 3102

Feb 2142.75 3045 2673

Mar 1752.67

2276 2098

Apr 1482.24 1389 1643

May 1089 897.29 1089

June 817 765.12 817

July 757 689.89 757

Aug 666 678.07 666

Sept 683 641.54 683

Oct 946.72 899

Nov 1271.25 1526

Dec 1937.5 2424

Total 11,496.95 17,708.38 0.00 18,377.00

Av. & Max 1,277.44 1,475.70 0.00 #DIV/0! 1,531.42


2012 2011 2010


Jan 279 303 279

Feb 264 307 264

Mar 197

321 197

Apr 339 269 339

May 247 265 247

June 268 226 268

July 229 184 229

Aug 190 189 190

Sept 188 177 188

Oct 237 184

Nov 249 239

Dec 334 232

Total 2,201.00

3,061.00 2,856.00

Av. & Max 244.56 255.08 238.00


Innisfil Recreational Centre

2012 2011 2010


Jan 424693.2 734.94 402597 728 392777 675

Feb 396465.1 836.1 370024 707 372940 861

Mar 423656 736.92 407501 713 418997 721

Apr 373861.5 714.24 393865 720 329439 750

May 389891.4 757.44 405085 729 349603 623

June 394959.2 865.8 342104.5 699 344663 712

July 432874.6 803.7 430928.9 804 363090 717

Aug 427792.5 806.4 456468 876 420037 761

Sept 372314.4 803.52 438240.5 844 414631 746

Oct 447607.6 732 451512 853

Nov 422630.8 712.62 410614 718

Dec 414610.2 714.6 393029 696

Total 3,636,507.90 4,931,662.50 4,661,332.00

Av. & Max 404,056.43 865.80 410,971.88 876.00 388,444.33 861.00

Stroud Arena

2012 2011 2010


Jan 120441.1 274.8 141589 283 95167 276

Feb 125599.2 269.76 163511 267 100583 265

Mar 273.36 86140 269

Apr 28514.45 119.28 59834 235 24501 81

May 34357.84 101.76 44101.58 104 37654 111

June 33797.16 82.56 38943.5 101 32238 111

July 41211.71 102.18 42812.06 110 38686 115

Aug 46615.31 194.04 67828.75 232 34043 159

Sept 104911.4 241.38 113993.5 276 101614 267

Oct 129210 282

Nov 138494.4 278.4 118894 284

Dec 139268.1 274.8 114251 275

Total 535,448.17 950,375.89 912,981.00

Av. & Max 66,931.02 274.80 95,037.59 283.00 76,081.75 284.00


Lefroy Arena

2012 2011 2010


Jan 72642.96 168 80810 149 71998 151

Feb 70923.6 165 79735 161 64261 153

Mar 60000 168.4 68774 158 64691 143

Apr 12855.33 71.7 24716 162 23211 148

May 17550.8 52.9 12250.44 70 5588 36

June 14331.35 47.95 6232.68 40 4513 38

July 14080.05 52.1 7522.2 34 10746 34

Aug 16433.64 49.75 4943.16 42 7092 24

Sept 51827.21 151.8 66410.28 154 33742 153

Oct 73932.48 167 82744 165

Nov 77371.2 171.4 71998 178

Dec 81239.76 174.6 67700 153

Total 330,644.94 583,937.20 508,284.00

Av. & Max 36,738.33 168.40 48,661.43 174.60 42,357.00 178.00


7.2- DEMAND RESPONSE PROVIDERS

ENERSHIFT

Contact Information:

Corporate Head Office

Rodan Energy

165 Matheson Blvd.E, Suite 6

Mississauga, Ontario L4Z 3K2

Main: (905) 625-9900

Fax: (905) 625-4307

Toll-free: (866) 999-5006

ENERNOC

Fast Facts

Program Period:

Year-round, weekdays

Program Options:

12:00PM – 6:00PM or 12:00PM – 9:00PM and 4:00PM – 9:00PM

Standby Notice:

Day-ahead or day-of, followed by an Activation Notice approximately 2 hours prior to a dispatch

Dispatch Duration:

4 hours

Dispatch Frequency:

Historically less than once a month


11-1155 North Service

Road West

Oakville, Ontario L6M 3E3

Office 416.800.0948

Fax 289.291.4001


ENERGY CURTAILMENT SPECIALISTS (ECS)

Program Option A Option B Option C

# Hour Called to Reduce

Up to 100 Hrs. annually Up to 200 Hrs. annually Up tp 100 Hrs. annually

Availability Hours

12pm-9pm in Summer 4pm-9pm rest of the year

12pm-9pm in Summer 4pm-9pm rest of the year

12pm-6pm year around

Event Notice Day-ahead or day-at-hand Day-ahead or day-at-hand Day-ahead or day-at-hand

Event Exposure

Max. 25 events at 4 hours/each



Use of On-site Generation

Yes, in general only natural gas units will qualify



Annual Payments

Payments based on zone Payments based on zone Payments based on zone


Energy Curtailment Specialists, Inc.

17-7000 McLeod Road Suite 153

Niagara Falls, Ontario, Canada L2G 7K3

Toll free phone: 877.711.5453

Toll free fax: 877.711.0506

Email: [email protected]

mailto:[email protected]

Appendix D

10 Year Fleet Plan

Equip. ID Year >Description Brand Purch Price Year Purchased

Estimated Life 2014 Value2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026

09-02 2009 2009 Volvo G960 Grader Volvo 355874.48 2009 15 380000460,200$

00-03 2000 Grader Champion 248862 2000 15 380000385,000$

09-04 2010 Combination Spreader / Dump Truck International 201106.54 2009 10 250220326,000$

13-05 2013 Tandem Axle Dump Freightliner 240988.54 2013 10 268300 421,900$ 13-06 2013 2013 4x4 Pick Up Ford 34051.88 2013 10 37000 58200

10-07 2010 3PT Roadside Mower New Holland 75848.4 2010 8 10000 12400 1810008-08 2008 Water/flusher/anti ice truck Sterling 260000 2008 10 310000

385,400$ 10-09 2010 2010 Ford 150 XLT 4X4 Ford 31242.36 2010 10 37000

48,200$ 12-10 2012 Trackless - Sidewalks Trackless 114721.18 2012 10 157280

214,800$ 08-11 2008 Tandem Axle Float Weber Lane 17124.48 2008 15 19500 25,400$ 14-12 2014 Tandem Axle Plow/Dump Combination

UnitMack 186723 2014 10 268300

442,200$ 01-13 2001 STEAMER Thompson 8204.34 2001 10 17500 1890007-14 2007 Flail Mower SEPPI 11048.4 2007 10 15000 17000

05-16 2005 2005 Ford 350 Econoline Passenger Van Ford 33793.59 2005 10 2850036,800$ 55,000$

13-17 2013 1 Ton Dump Service Truck Ford 67295 2013 10 71000111,600$

07-18 2007 Single Axle Trailer Intruder 2050 2007 15 2400

08-19 2008 2009 Sterling Plow Truck Sterling 178054.15 2008 10 250220

04-20 2004 6 Ton Singel Cab & Chassis Combo Sterling 152668.8 2004 10 250220 375,400$ 04-21 2004 Tandem Axle Dump Sterling 167997.22 2004 10 268300 349,600$ 05-22 2005 Kubota Tractor Kubota 50614.2 2005 10 60000 71,200$ 13-22 2013 2013 New Holland Bi-directional Tractor New Holland 133717.98 2013 10 135000 175900

03-23 2003 Tandem Axle Dump Freightliner 190000 2000 10 268300 421900

00-28 2000 Tandem Axel Dump Volvo 166021.36 2000 10 268300 28960011-30 2012 Dodge 4 x 4 pickup truck complete with

plow and tail gate sanderDodge 54562.75 2011 10 62000 88700

12-31 2012 Cat Backhoe Cat 106135.68 2012 10 110000 165000

06-32 2006 Articulated Wheel Loader Case 175350.96 2006 10 195000 210500 33680004-33 2004 Service Crane Truck Ford 92034.88 2003 10 114600 123700 19800092-34 1992 Tandem Axle Float Float King 11465.19 1992 15 26000 2810012-35 2012 Dodge Ram 1500 Quad Cab 4 x 4 Dodge 30341.75 2012 10 38000 63500

95-36 1995 Low Pressure STEAMER Thompson 7350.27 1995 10 17500 19800

10-37 2011 1 Tonne Service Service Truck Ford 63497.78 2010 10 71000 97000

12-39 2012 4x4 3/4 Ton Pick-up Dodge 46920.83 2012 10 52000 78000

14-48 2013 Single axle truck Freightliner 190009.33 2014 10 195000 292500

94-72 1994 Double Axle Trailer - Nish Nish 19205.45 1994 15 9500 10000

06-80 2006 Trackless MT5 - 2006 Trackless 122475.24 2005 10 157280 164800 259200

06-81 2006 Bandit Brush Chipper Bandit 37598.04 2006 10 44000 46100 72500

06-88 2006 Tandem Axle Dump Combo Freightliner 201701.88 2006 10 268300 303600 485800

Equip. ID Year >Description Brand Purch Price Year Purchased

Estimated Life 2014 Value2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026

06-89 2006 2007 Freightliner Freightliner 197560.08 2006 10 268300 303600 485000

07-92 2007 Street Sweeper Elgin 214090.56 2007 10 297000 320600

08-100 2007 Magnum Trailer Mounted Generator Magnum 29665 2008 15 34000 4640008-101 2008 Low Preassure Steamer Thompson Thompson 14221.09 2008 10 17500 19800

08-102 2008 Tandem Axle Vactor/Vacuum Truck Vactor 376971.2 2008 8 415500 470200

09-103 2009 6" trailer mounted Water pump Thompson 35995 2009 15 39500 59300

09-109 2009 2009 Ford F-450 Ford 65960.86 2009 10 71000 92500

10-114 2010 Portable Traffic Light North America T ffi

18500 2010 10 20500 25500

10-115 2010 Portable Traffic Light North America 18500 2010 10 20500 2550010-128 2010 Tandem Axle Dump Combo International 227320.52 2010 10 268300 366400

10-129 2010 Tandem Axle Dump Combo International 227203.5 2010 10 268300 366400

10-130 2010 Tandem Axle Dump Combo International 227534.21 2010 10 268300 366400

09-131 2009 'Trackless MT6 - 2009 w. new 51" Blower Trackless 97524.24 2010 10 157280 186500

10-132 2011 4x4 Crew Cab c/w 8' box 3/4 ton pickup Dodge 45348.98 2010 10 52000 67800

11-134 2011 Trialer Mounted Sign Board ADDCO 23165 2011 10 26000 3390012-142 2012 Falcon Road Maintenance Equipment Falcon 27024.14 2012 10 34000 46400

New 2015 Tandem Axle 10 268300 289600 463500New 2015 Hotbox 10 34000 35600 53500New 2016 Street Sweeper 10 297000 311300 489500New 2016 Forestry Truck 10 241920 253600 398700New 2016 Sidewalk Machine 10 157280 164800 259200New 2016 3/4 tonne 10 52000 58800 89800New 2017 Forestry Chipper 10 44000 52200New 2017 5 mt Plow/Dump 10 268300 318200New 2017 Sidewalk Vacuum 10 119500 129000New 2017 Skid Steer 10 47000 54000New 2018 3/4 tonne 10 52000 64600New 2021 Tandem 10 268300 384000New 2021 Side Walk Machine 10 157280 204900New 2022 3/4 tonne 10 52000 78000

995,800$ 1,991,600$ 981,100$ 1,000,300$ 1,070,600$ 1,247,200$ 711,500$ 692,100$ 1,214,900$ 1,629,600$ 1,106,800$ 2,557,800$

Appendix E

2011 Innisfil Energy Usage

Press TAB to move to input areas. Press UP or DOWN ARROW in column A

Confirm consecutive 12-month period (month-year to month-year) 01-11 to 12-11Type of Public Agency (Sector): MunicipalAgency Sub-sector MunicipalityOrganization Name Town of Innisfil

Gatsby Administration Centre Administrative offices and related facilities, including municipal council chambers 512 Smithson Avenue Toronto M7A 2J1Fire Station 1 Alcona Fire stations and associated offices and facilities 780 Innisfil Beach Road Innisfil L9S 2C3Fire Station 2 Lefroy Fire stations and associated offices and facilities 885 Ardill Street Innisfil L0L 1W0Fire Station 3 Stroud Fire stations and associated offices and facilities 2394 Victoria Street Innisfil L9S 1K5Fire Station 4 Cookstown Fire stations and associated offices and facilities 23 King Street North Innisfil L0L 1L0Churchill Community Centre Community centres 6322 Yonge Street Innisfil L0L 1K0Cookstown Fairground Quonset Hut Storage facilities where equipment or vehicles are maintained, repaired or stored 18 Church Street Innisfil L0L 1L0Old Cookstown Library Cultural facilities 19 Queen Street Innisfil L0L 1L0Cookstown Teatre Performing arts facilities 1 Hamilton Street Innisfil L0L 1L0Innisfil Recreation Centre Indoor Ice Rink Indoor ice rinks 7315 Yonge Street Innisfil L9S 4V7Innisfil Recreation Centre Gyms & Indoor Courts Gyms and indoor courts for playing tennis, basketball or other sports 7315 Yonge Street Innisfil L9S 4V7Innisfil Recreation Centre Indoor Swimming Pool Indoor swimming pools 7315 Yonge Street Innisfil L9S 4V7Innisfil Recreation Centre Indoor Recreational Facility Indoor recreational facilities 7315 Yonge Street Innisfil L9S 4V7Innisfil Beach Park Gatehouse Administrative offices and related facilities, including municipal council chambers 676 Innisfil Beach Road Innisfil L9S 4H6Knock Community Centre Building Community centres 7756 10th Sideroad Innisfil L9S 3K8Lefroy Arena Ice Rink Indoor ice rinks 1354 Killarney Beach Road Innisfil L0L 1W0Lefroy Arena Banquet Hall Community centres 1354 Killarney Beach Road Innisfil L0L 1W0Town Hall Administration Building Administrative offices and related facilities, including municipal council chambers 2101 Innisfil Beach Road Innisfil L9S 1A1Old Town Hall Administration Building Administrative offices and related facilities, including municipal council chambers 2147 Innisfil Beach Road Innisfil L9S 1A1Stroud Arena Indoor Ice Rink Indoor ice rinks 7883 Yonge Street Innisfil L9S 1K8Stroud Arena Banquet Hall Indoor recreational facilities 7883 Yonge Street Innisfil L9S 1K8Stroud Arena Public Library Public libraries 7883 Yonge Street Innisfil L9S 1K8Alcona Lakeshore Library Public libraries 967 Innisfil Beach Road Innisfil L9S 1V3Churchill Library Public libraries 2284 4th Line Innisfil L0L 1K0New Cookstown Library Public libraries 20 Church Street Innisfil L0L 1L0New Cookstown Library Community Centre Community centres 20 Church Street Innisfil L0L 1L0Roads Operation Centre Garage Storage facilities where equipment or vehicles are maintained, repaired or stored 2183 Innisfil Beach Road Innisfil L9S 1A3Roads Operation Centre Office Administrative offices and related facilities, including municipal council chambers 2183 Innisfil Beach Road Innisfil L9S 1A3Cookstown Waste Water Control Plant Facilities related to the treatment of sewage 1315 Victoria Street Innisfil L0L 1L0Waste Water Admin Building Facilities related to the treatment of sewage 1578 Saint Johns Sideroad Innisfil L9S 4T9Waste Water Pump Station 1 - Tent City Facilities related to the pumping of sewage 1236 Maple Road Innisfil L9S 4R1Waste Water Pump Station 2 - Little Cedar Point Facilities related to the pumping of sewage 690 6th Line Innisfil L9S 4R7Waste Water Pump Station 3 - Big Cedar Point Facilities related to the pumping of sewage 1692 Cedar Grove Avenue Innisfil L9S 4M4Waste Water Pump Station 5 - Lefroy Facilities related to the pumping of sewage 1208 Killarney Beach Road Innisfil L0L 1W0Waste Water Pump Station 4 - Alderslea Facilities related to the pumping of sewage 2298 Crystal Beach Road Innisfil L9S 2E3

Please fill in the mandatory fields indicated in red, in addition to submitti

Postal Code

Energy Consumption and Greenhouse Gas Emissions Reporting - for 2011

Operation Name Operation Type Address City

Waste Water Pump Station 6 - IRC Facilities related to the pumping of sewage 2101 Innisfil Beach Road Innisfil L9S 1A1Waste Water Pump Station 7 - Letizia Facilities related to the pumping of sewage 992 Leslie Drive Innisfil L9S 2B23rd Line Booster Water Pump Station Facilities related to the pumping of water 1543 3rd line Innisfil L0L 1W0Churchill Pump Station - Well 3 Facilities related to the pumping of water 2583 4th Line Innisfil L0L 1K0Churchill Water Pump Station - Well 1&2 Facilities related to the pumping of water 212 Valleyview Drive Innisfil L0L 1K0Cookstown Water Pump Station - Well 1 Facilities related to the pumping of water 48 Queen Street Innisfil L0L 1L0Cookstown Water Pump Station - Well 2 & 4 Facilities related to the pumping of water 3948 Victoria Street Innisfil L0L 1L0Cookstown Water Pump Station - Well 3 Facilities related to the pumping of water 1315 Victoria Street Innisfil L0L 1L0Goldcrest Water Pump Station Facilities related to the pumping of water 2067 Fennel Drive Innisfil L0L 1R0Innisfil Heights Water Pump Station - Well 2 & 3 Facilities related to the pumping of water 2223 Industrial Park Road Innisfil L9S 3V9Innisfil Heights Water Reservoir Facilities related to the pumping of water 1976 Commerce Park Drive Innisfil L9S 4A3Lake Shore Water Filtration Plant Facilities related to the treatment of water 2155 25th Sideroad Innisfil L9S 2G9Low Lift Water Treatment Building - IBP Facilities related to the pumping of water 676 Innisfil Beach Road Innisfil L9S 4H6IRC Water Pump Station Facilities related to the pumping of water 2101 Innisfil Beach Road Innisfil L9S 1A1Stroud Water Pump Station 1 & 2 Facilities related to the pumping of water 221 Sunset Crescent Innisfil L9S 1J3Temp Booster Pump Station Facilities related to the pumping of water 1610 Innisfil Beach Road Innisfil L9S 4N9Zone 2 Booster Water Pump Station Facilities related to the pumping of water 2098 Webster Boulvard Innisfil L9S 2A3

361,280.00 Square feet 40 5,103,348.00000 kWh 410,325.00000 Cubic meter9,720.00 Square feet 168 74,253.00000 kWh 12,124.00000 Cubic meter1,615.00 Square feet 10 22,513.00000 kWh 5,311.00000 Cubic meter

10,753.00 Square feet 168 57,613.00000 kWh 19,372.00000 Cubic meter2,454.00 Square feet 10 23,528.00000 kWh 9,604.00000 Cubic meter5,306.00 Square feet 30 53,152.00000 kWh 5,690.00000 Cubic meter4,000.00 Square feet 1 1,198.00000 kWh 20.00000 Litre1,326.00 Square feet 0.2 2,941.00000 kWh 2,670.00000 Cubic meter5,060.00 Square feet 10 13,782.00000 kWh 3,698.00000 Cubic meter

86,975.00 Square feet 122 2,837,424.00000 kWh 300,884.00000 Cubic meter9,676.00 Square feet 105 320,354.00000 kWh 33,971.00000 Cubic meter

31,434.00 Square feet 105 1,006,828.00000 kWh 106,765.00000 Cubic meter12,340.00 Square feet 105 411,884.00000 kWh 43,677.00000 Cubic meter

812.00 Square feet 29 33,876.00000 kWh1,264.00 Square feet 10 8,189.00000 kWh 1,938.00000 Cubic meter

27,168.00 Square feet 56 436,220.00000 kWh 27,261.00000 Cubic meter5,133.00 Square feet 8 83,089.00000 kWh 5,193.00000 Cubic meter

37,000.00 Square feet 59 533,456.00000 kWh 46,753.00000 Cubic meter10,635.00 Square feet 0.2 81,946.00000 kWh 5,641.00000 Cubic meter43,317.00 Square feet 56 753,598.00000 kWh 37,173.00000 Cubic meter11,064.00 Square feet 15 196,142.00000 kWh 9,675.00000 Cubic meter

4,547.00 Square feet 47 82,586.00000 kWh 4,074.00000 Cubic meter11,506.00 Square feet 49 172,438.00000 kWh 14,849.00000 Cubic meter

1,784.00 Square feet 26 14,589.00000 kWh 943.00000 Cubic meter6,530.00 Square feet 39 122,754.00000 kWh 2,160.00000 Cubic meter3,012.00 Square feet 6 57,767.00000 kWh 1,016.00000 Cubic meter9,434.00 Square feet 73 97,342.00000 kWh 36,399.00000 Cubic meter

784.00 Square feet 48 8,465.00000 kWh 3,165.00000 Cubic meter168 183.00000 207,672.00000 kWh168 3045.00000 2,877,892.00000 kWh 255,564.00000 Cubic meter168 450.00000 108,157.00000 kWh168 16.00000 13,648.00000 kWh168 2579.00000 296,518.00000 kWh168 36.00000 15,604.00000 kWh168 1526.00000 140,672.00000 kWh

Electricity Natural GasAnnual Flow (Mega Litres)

Energy Type and Amount Purchased

CoalFuel Oil 1 & 2

ing data on your energy

WoodFuel Oil 4 & 6 PropaneAverage # Hours

Per WeekTotal Floor Area of the Indoor Space in

which Operation is Conducted

168 29.00000 36,839.00000 kWh168 13.00000 2,710.00000 kWh168 1262.00000 299,006.00000 kWh168 45.00000 40,786.00000 kWh168 46.00000 99,707.00000 kWh168 6.00000 12,884.00000 kWh168 6.00000 21,436.00000 kWh168 11.00000 71,318.00000 kWh168 35.00000 61,052.00000 kWh168 81.00000 95,481.00000 kWh168 78.00000 91,081.00000 kWh168 2636.00000 1,069,155.00000 kWh 82,484.00000 Cubic meter168 2810.00000 528,219.00000 kWh168 42.00000 53,012.00000 kWh168 362.00000 332,103.00000 kWh168 42.00000 53,012.00000 kWh168 38.00000 96,118.00000 kWh

Renewable?

Emission

Factor Renewable?If Yes, enter

Emission Factor GHG Emissions (Kg) Energy Intensity (ekWh/sqft)Energy Intensity

(ekWh/Mega Litres)25.64000 Giga Joule - steam or hot water No 23.40500 Giga Joule - chilled watNo Click above cell to toggle units Click above cell to toggle u

28,862.20175 20.8954911,842.16000 48.8898641,234.26624 24.5042620,039.82171 51.1805915,009.82763 21.41426

126.71968 0.334655,283.25409 23.617778,094.09865 10.49081

795,853.33427 69.3895089,854.80982 70.42065

282,399.03166 68.12695115,527.63548 70.99460

2,710.08000 41.719214,319.15513 22.77344

86,437.98265 26.7205516,465.14601 26.93923

131,068.96413 27.8469317,220.70691 13.34248

130,568.11747 26.5176333,983.17623 27.0214914,309.29440 27.6849741,868.96032 28.70240

2,949.98126 13.7954013,904.07432 22.31394

6,542.23703 22.7638876,604.29217 51.32313

6,661.03446 53.7014216,613.76000 1,134.81967

713,407.55863 1,837.099908,652.56000 240.348891,091.84000 853.00000

23,721.44000 114.974021,248.32000 433.44444

11,253.76000 92.18349

and Consumed in Natural Units Total (These columns will calculate when file is Saved)

District Heating District Cooling

2,947.12000 1,270.31034216.80000 208.46154

23,920.48000 236.930273,262.88000 906.355567,976.56000 2,167.543481,030.72000 2,147.333331,714.88000 3,572.666675,705.44000 6,483.454554,884.16000 1,744.342867,638.48000 1,178.777787,286.48000 1,167.70513

241,478.87747 738.1549942,257.52000 187.97829

4,240.96000 1,262.1904826,568.24000 917.41160

4,240.96000 1,262.190487,689.44000 2,529.42105

Energy Conservation and Demand Management Plan...Town of Innisfil Energy Conservation and Demand...

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