Boiler Basics Workshop - For Homes - Enbridge Gas …€¦ · · 2014-12-01•Typical range is 3% – 6% of feedwater 37 . ... Test Boiler #1 Boiler #2 Feedwater Condensate Softener

Boiler Basics Workshop

November 13th, 2014

Trevor Van Eerde, P. Eng., CEM Industrial Energy Solutions Consultant Enbridge Gas Distribution Inc. 647-408-6743 [email protected]

• Enbridge Programs

• Boiler Basics

• Energy Savings Opportunities in Boilers

• Limited Time Campaign

2

Today’s Workshop Will Cover:


• Boiler Basics



3


Enbridge DSM program :

• In existence for 20 years;

• Gained Customer trust through experience and involvement;

• Auditing process in place to ensure calculated savings are realistic.

Industrial Program

4

Knowledge

Development : Arming

our customers with

information. Opportunity

Identification

: Testing and

energy use

analysis.

Measurement :

Choosing the right

metering methods

to quantify key

energy inputs.

Engineering

Analysis : Analyzing

and interpreting data

to

monetize savings

opportunities.

Action and

Implementation

5

Industrial Program

Helped our customers save :

• Approx. 110,000,000 m3 of natural gas

• More than 20,000,000 KWh of electricity

• Over 800,000 m3 of water

• In three year period ALONE

Participating in our programs helps YOU :

• Reduce C02 emissions

• Improve BOTTOM LINE

6

Approach to Energy Savings

7

Energy Flow

Meter Energy

Converter

Distribution

System End User Need /

Requirement

Energy Savings Strategy


• Boiler Basics



8


Energy in a boiler room

• Energy can be defined as the ability to do work

• In the boiler room energy is typically measured in British Thermal Units – or BTU’s

– 1 BTU is the energy required to raise 1lb of water 1°F

– M in front of BTU’s = x 1000, MM = x 1,000,000

• Power, the rate at which energy is transferred, is typically measured in BTU/hr

– How many BTU’s the boiler can generate in 1 hour

• Specific Energy Content – BTU/lb

– How many BTU’s are in 1lb of water, or 1lb of steam

• Reference card included in your information package

9

Steam Basics

10

• Water as we know it can exist in 3 states

– Solid – Liquid – Gas (Vapour)

• Steam, water vapour, is generated by adding heat energy to water to bring it to its boiling temperature (sensible heat)

• Adding more energy transforms water from liquid to vapor (latent heat)

• Steam is used to carry heat energy from one location to another

– Steam is an excellent energy transporter

11

Heat Energy is also called Enthalpy (h):

Energy due to both Temp. and Pressure

Steam Basics

Energy in Water vs. Temperature

12

ENERGY

Energy Removed Energy Added

Tem

pera

ture

Water & Steam

Ice & Water

Ice Wa

ter

On

ly

Latent Heat Latent Heat Sensible

Heat

Sensible

Heat

Steam Only

100°C for Water

0°C for Water

Sensible

Heat

Energ

y A

dde

d (

BT

U’s

)

• Heat energy required to make steam has two components:

– Sensible heat (Btu/lb)

– Latent heat (Btu/lb)

• Sensible Heat

– Amount of heat required to raise the temperature of water from 32°F to its boiling point (saturated water)

– Adding sensible heat raises the temperature

– It can be detected with a thermometer

– Sensible heat, or enthalpy of water at 32°F, is taken as 0 BTU/lb

13

Steam Basics – Sensible vs. Latent Heat

• Amount of heat required to change saturated water to steam

• Adding Latent Heat does not raise the temperature: the boiling water and steam has the same temperature for a given pressure

• Latent heat added to the boiler is what is transferred to the load

• Removing latent heat at the load creates condensate

• Returning maximum amount of condensate reduces heat energy required by the boiler

14

Steam Basics – Latent Heat

15

Increasing Pressure increases Boiling Point (saturated water temp.)

0 psig

100

150

200

250

300

350

400

450

0 50 100 150 200

Sa

tura

tio

n T

em

p (

°F)

Pressure (psig)

Saturation Temperature vs. Pressure

212°F

100 psig

338°F

Steam Basics – Pressure Dependency

• Total Heat of Steam = hg

• Sensible Heat = hf

• Latent Heat = hfg

For 100 psig steam:

hf (saturated liq. Enthalpy) = 309 Btu/lb

hfg (latent heat) = 880 Btu/lb

hg (saturated vapour enthalpy) = 1189 Btu/lb

16

Total Heat of Steam = Sensible Heat + Latent Heat

Steam Basics – Total Heat of Steam

0

200

400

600

800

1000

1200

1400

Latent Heat

Sensible Heat

338°F

Total heat of Steam at 100 psig

100 psig

Pressure (psig)

Hea

t (B

tu/lb

)

880

309

338°F

32°F

Steam Table Example

• Properties for 100psig?

17

• Saturation Temperature = 338°F

• hf = 309 BTU/lb

• hfg = 880 BTU/lb

• hg = 1180 BTU/lb

What is a boiler?

• Closed pressure vessel

• Used to convert potential energy from a fuel into thermal energy

– Combustion process

• Thermal energy released from the fuel is then transferred into a medium (water, oil, etc.)

– Heat transfer tubes, coil tubes

• Energy in the medium is then sent to the distribution system to be used in the load

– Steam headers, pipes, etc.

18

19

Boiler: 300BHP (10 MMBTU/hr) Plant Operating Hours: 6,000 hrs.

Average Loading: 50% Annual Fuel: 1,000,000m3/yr ($280,000/yr)

Workshop Steam Plant

DEAERATOR

8 psig

Cond.

Tank

Make-Up

Water – 50%

Condensate

Return – 50%

180 °F

Natural Gas

Process Steam Sat. Steam @ 100 psig

Stack Flue Gas

Blowdown

DA Steam

Boiler

Feedwater

Energy Losses in Boilers

• Improvement in Boiler Efficiency is achieved by reducing losses

• Three main boiler losses

• Stack Losses

• Blowdown Losses

• Radiation Losses

• Focus on Stack losses and Blowdown losses

20

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater




• Stack Losses

• Blowdown Losses


21

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater

Stack Losses

• Stack losses are typically the largest boiler system loss

• Result of:

– Combustion process

• Poor conversion of fuel into thermal energy

• Water generated during combustions process

– Insufficient heat transfer

• Poor transfer of thermal energy from fuel into boiler feedwater

• Energy that is not transferred into the feedwater leaves through the stack

22

23

Air : Fuel Ratio (by vol.) = 9.5 : 1 or 10:1

(approx.)

Perfect Combustion: Ideal Air:Fuel Ratio

CO2 + 2H2O + 7.52 N2

Natural Gas (CH4 ) 1 ft3

16 lbs.

Air( 2O2 + 7.52 N2) 9.52 ft3

275 lbs.

O2 contributes to

combustion, while

N2 absorbs heat.

Heat Released =1012 Btu/ft3

= 23,000 Btu/lb

Air Fuel Mixture

24

Flu

e G

as L

oss

Total Air

Excess Air

( High O2)

rich lean stoich

Maximum

Efficiency Zone

Unburned

Fuel

(CO)

Example # 1 – Reading a combustion test strip

25

Flue Gas Temperature

Combustion Efficiency

%O2

Carbon Monoxide

% Excess Air

Combustion Efficiency Chart

26


27

Decreasing Efficiency


28

Decreasing Efficiency

Use the Combustion Efficiency Chart to determine the combustion

efficiency based on the following parameters:

Parameters

Excess O2 = 8%

Flue Gas Temp. Tfg = 460 °F

Combustion Air Temp. Tair = 80 °F

Calculate Delta T = (460 – 80) °F

= 380 °F

O2 340 360 380 400 420

7.00 80.6 80.1 79.5 79.0 78.4

7.50 80.4 79.8 79.2 78.6 78.0

8.00 80.0 79.4 78.9 78.3 77.7

8.50 79.7 79.1 78.5 77.9 77.2

Excess, % FG Temperature - Combustion Air

Example #2 – Reading a combustion efficiency chart

29

30

Combustion test strip

31

Enbridge Can Help!

Flue Gas Analyzers Are Used To Measure Combustion Efficiency

Typical Readings

• Flue gas temperature

– Approximately 115°F above saturation temperature of steam

– Ex. 100psig, Saturation temperature 338°F, would expect 453°F stack temperature

– If there is a feedwater economizer, closer to saturation temperature, 353°F

• Oxygen (O2%)

– 4-6%

– Likely higher percentages at low fire, this is normal

• Carbon Monoxide (CO%)

– < 200ppm

– High CO levels are a safety concern

• Readings outside of these ranges should be investigated further

32




• Stack Losses

• Blowdown Losses


33

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater

34




DEAERATOR

8 psig

Cond.

Tank

Make-Up

Water – 50%

Condensate

Return – 50%

180 °F

Natural Gas


Stack Flue Gas

Blowdown

DA Steam

Boiler

Feedwater

Water Treatment Issues

• Oxygen pitting and corrosion in the boiler can cause boiler tube failures

• Mineral deposits and scale on boiler tubes reduce efficiency and can ultimately cause boiler tube failures

• Boiler water carryover into the steam network reduces steam system efficiency and can cause equipment damage

• Condensate network corrosion can cause piping and steam control equipment to fail

35

Blowdown Basics

• When water is boiled, steam is generated

• Solids are left behind:

– Suspended solids form sludge which degrades heat transfer

– Dissolved solids promote foaming and water carryover

• Water is discharged to keep solids within acceptable limits

– Bottom blowdown from mud drum removes suspended solids (once/twice a day)

– Surface blowdown removes dissolved solids, concentrated near liquid surface (continuous)

36

Blowdown Basics

• Insufficient BD leads to carryover and deposits

• Excessive BD leads to wasted energy, water and chemicals

• Blowdown water temp. is same as steam

• Typical range is 3% – 6% of feedwater

37

Oxygen Pitting

38

Image courtesy of www.gewater.com

Mineral Scale

39

Image courtesy of http://theapexsolution.files.wordpress.com/2012/11/scaled-boiler.jpg

Boiler Water Treatment Report

Test Boiler #1 Boiler #2 Feedwater Condensate Softener

Hardness (ppm) 0 0 0 0 0

Limits 0-6 0-6 0-2 0-4 0-3

Sodium Sulphite (ppm) 75 75 25

Limits 50-100 50-100 6-50

pH 11.5 11.5 8

Limits 9.8-11.8 9.8-11.8 7.5-10.5

Conductivity (umhos) 3500 3500 20

Limits 3000-4000 3000-4000 0-100

Chloride (ppm)

Total Alkalinity (ppm) 250 250

Limits 150-700 150-700

P Alkalinity (ppm) 200 200

Limits 150-700 150-700

Iron (ppm) 0

Limits 0-0.1

40

Additional information in your water report

• Make-up water meter readings

– How much fresh water you top up to the system

• ?????

41


• Boiler Basics



42


Approach to Energy Savings

43

Energy Flow

Meter Energy

Converter

Distribution

System End User Need /

Requirement

Energy Savings Strategy

44




DEAERATOR

8 psig

Cond.

Tank

Make-Up

Water – 50%

Condensate

Return – 50%

180 °F

Natural Gas


Stack Flue Gas

Blowdown

DA Steam

Boiler

Feedwater

Steam Distribution and End User Savings

• Not the main focus for this workshop

• Minimize steam requirements at end user

– Lower set points, pressure, less hot water, etc.

• Efficient transportation and heat transfer

– Fouled heat exchangers

– Insulation, steam traps

– Condensate return

• Enbridge portal can be used

for insulation

• See portal card in your portfolio

45

Gas Savings Opportunities in Boilers



• Stack Losses

• Blowdown Losses


• Focus on Stack losses and Blowdown losses

46

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater




• Stack Losses

• Blowdown Losses


47

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater

• Stack loss is a major source of heat loss

48

Gas Savings Opportunity – Stack Loss

Qng = 100%

Natural Gas

Qsl = 21%

Stack

Qst Steam flow

Qbd = 0.7% (4% of FW)

Blowdown Qfw

Feedwater

Qra = 2.5%

(1% of boiler rating)

Gas Savings Opportunities – Stack Loss

• Stack loss can be reduced by:

1. Improving combustion

• Reduce excess air (O2)

• Reduce/eliminate CO and CxHy

• Controls

2. Reducing flue gas temperature

• Recover heat from hot flue gases

• (40°F drop = 1% efficiency improvement)

• Economizers

3. Increasing combustion air temperature

• Draw air from a high point in the boiler room

49

Air

CO2 + 2H2O + X 2O2 + (1 + x) 7.52 N2

• Excess air is required to achieve proper combustion

• Excess air wastes heat as air enters at ambient temp. and leaves at stack temp.

o 79% of air goes for a free ride

How much excess air is required?

• Depends on burner design, boiler configuration, air/fuel control, etc.:

o Older coil-tube boilers without Linkageless Controls (LLC) have high excess O2 : (5% – 12%)

o Fire-tube boilers generally have lower excess O2 :(4% – 9%)

o Large water-tube boilers can achieve lower excess O2 : (2% - 6%)

50

Reducing Excess O2

51

O2 340 360 380 400 420

4.00 82.0 81.5 81.1 80.6 80.1

4.50 81.8 81.3 80.8 80.4 79.9

5.00 81.6 81.1 80.6 80.1 79.6

5.50 81.4 80.9 80.4 79.9 79.3

6.00 81.2 80.6 80.1 79.6 79.0

6.50 80.9 80.4 79.8 79.3 78.7

7.00 80.6 80.1 79.5 79.0 78.4

7.50 80.4 79.8 79.2 78.6 78.0

8.00 80.0 79.4 78.9 78.3 77.7

8.50 79.7 79.1 78.5 77.9 77.2

Excess, %FG Temperature - Combustion Air

Use the Combustion Efficiency Chart to calculate the cost savings

associated with reducing excess O2 levels from 8% to 5%.

Example # 3: Excess O2 Cost Savings

Ƞold = 78.9 %

Calculate new ƞ

Ƞnew = 80.6 %

- Minimal Cost

- 300BHP, 50%

loaded –

17,000m3/yr

- $4760/yr

52

Linkageless Controls

Maintain optimum air:fuel ratio at all firing rates to run boilers safely at optimum combustion efficiency

Monitor process boiler temperature and pressure and quickly respond to changes in load

53

Purpose of Combustion Controls:

• Mechanical system using cams, linkages and jackshafts to characterize the air:fuel ratio

• A single actuator motor adjusts its jackshaft arm according to master load (demand) signal

• As the actuator motor moves the jackshaft, the arms connected to the fuel valve and air fan damper move with it

• Air:fuel ratio is set by adjusting the cam

• Calibrating involves combustion tests in which actuator is positioned to various settings, usually at least 10, and at each setting setscrews are adjusted to achieve the desired O2 level in flue gas

54

Linkage Combustion Controls

Microprocessor

Controller

Natural Gas

Combustion

Air Blower

Primary Actuator

Motor

Valve

Valve

Linkage

Linkaged Combustion Control System

• Hysteresis or drift caused by wear, tear and slop in linkages

• Control devices do not return to the same position during boiler ramp-up or turn-down

• Air : fuel ratio is typically set high to compensate for hysteresis

• Air : fuel ratio generally drifts after tune-up

55

Issues with Linkage Controls:

0

1

2

3

4

5

6

7

8

9

10

0 20 40 60 80 100 120

Oxy

gen

%

Firing Rate %

Boiler 2 Combustion

Oxygen

• Obviously no linkages

• Individual servomotors attached to gas valve and air damper. Position of each motor is programmed independently

• A programmable control unit provides precise air:fuel ratio over entire range

• No hysteresis for a properly tuned and maintained LLC system

• Additional controller can be added to provide O2 trim

56

Linkageless Combustion Controls

Linkageless Combustion Control System

New

Microprocessor

Controller

Natural Gas

Combustion

Air Blower

Servo

Driven

Valve

Servo

Driven

Valve

57

Linkages Linkageless with Honeywell LLC

Power Flame Boiler Burner

1. No hysteresis

o Function of “Base Case” burner age

2. Improved combustion efficiency due to:

o Reduced excess air

o Accurate characterization of air:fuel ratio

o Accurate control of firing rate

o Depends on how much excess O2 can be reduced

3. Reduced cycling due to improved turn-down

o Savings are a function of “Base Case” burner turndown

4. Additional savings due to O2 trim

58

Gas Savings Opportunity: Linkageless Controls

Example # 4 : Linkageless Controls • Reduce O2,Maintain optimum air/fuel all the time

59

Improvement Savings

Removal of hysteresis 0.50 %

Improved combustion 2.19 %

Increased turndown 0.13 %

Total 2.82 %

Annual gas savings 29,720 m3/yr

Annual savings $8,322

Estimated installed cost $15,000

Simple payback period 1.8 years

Enbridge incentive $5,944

Revised simple payback period 1.1 years

Personal experiences with LLC

• Some vendors claim 10 - 15% savings, based on unrealistic assumptions

– Typical 2.5% - 4%

• Savings possible if burner is in very bad condition with very high O2, CO, Combustibles, Cycling etc.

• Need to establish “base case” performance

• Important to estimate savings based on a real “base case”

• Your ESC will help you establish a base line to calculate realistic savings

60

61

Flue Gas Heat Recovery with

Feedwater Economizers

62




DEAERATOR

8 psig

Cond.

Tank

Make-Up

Water – 50%

Condensate

Return – 50%

180 °F

Natural Gas


Stack Flue Gas

Blowdown

DA Steam

Boiler

Feedwater

320°F

63

Gas Savings Opportunity: Feedwater Economizers

DEAERATOR

8 psig

Natural Gas

Stack Flue Gas

Boiler

Feedwater

Feedwater

Economizer

230°F

450°F

267°F

O2 200 220 240 260 280 300 320 340 360 380

4.50 85.3 84.8 84.3 83.8 83.3 82.8 82.3 81.8 81.3 80.8

5.00 85.1 84.6 84.1 83.6 83.1 82.6 82.1 81.6 81.1 80.6

5.50 85.0 84.5 84.0 83.5 82.9 82.4 81.9 81.4 80.9 80.4

Excess, % FG Temperature - Combustion Air Temp, °F

Feedwater Economizer

• Heat recovery from flue gases reduces stack temperature

– Sensible heat recovery

• Efficiency gain can be read from combustion chart

64

Parameters

Ƞw/o econo. = 80.6 %

O2 = 5%

Tout = 320 °F

Tair = 70 °F

Delta T = 250 °F

Ƞnew = 83.9 %

450 °F

320 °F

230 °F

267 °F



65

Example 5 : Installing a Feedwater Economizer

• 300BHP Boiler, 50% average loading, 6000hrs/yr

• Reduction of Flue Gas temperature from 450°F to 320°F

Parameter Savings

Average Hourly Heat Recovery 208,259 BTU/hr


Annual savings $12,523 /yr

Percentage of total load 4.2%



Typical savings of 3-6%

66

Flue Gas Heat Recovery with

Condensing Economizers

When 1 molecule of CH4 is burned, it produces 2 molecules of H2O

67

• 1 lb of CH4 produces 2.25 lb of water

• 1 lb of Natural Gas produces 2.14 lb of water

CH4 + 2O2 + 7.52 N2 CO2 + 2H2O + 7.52 N2

2.25 lb 1 lb

Basic Concept of Condensing Heat Recovery

• Water in products of combustion is vaporized due to heat of combustion

• Water vapours absorb about 10% of fuel input

• Energy is lost to atmosphere with exhaust gases through stack

• Heat of vaporization can be recovered if flue gases are cooled below water dew point

• When water vapour condenses, it releases heat of vaporization

– Latent heat recovery

• Condensing economizer recovers both:

1. Heat of condensation (latent heat)

2. Sensible heat

68

Basic Concepts of Condensing Heat Recovery

Air

CO2 + 2H2O + 7.52 N2

NG

Condensation starts

below dew point at

about 137 °F

Sensible

heat only

Sensible and

latent heat

69 Excess O2 = 5%

As flue gas

temperature

decreases,

efficiency increases

Available Heat Varies with FG Temp. leaving Economizer

0

0.2

0.4

0.6

0.8

1

1.2

1.4

1.6

75 F 100 F 125 F 150 F

Latent Heat

Sensible Heat

Heat available from one boiler

Flue Gas Temp. Leaving Condensing Economizer (°F)

Heat A

vaila

ble

(M

MB

TU

/hr)

1.39

1.11

0.61

0.38

0.82

0.61

0.17

0.38 0.44

0.50 0.56

70

100°F

71

Gas Savings Opportunity: Condensing Economizer (In-line)

DEAERATOR

8 psig

Stack Flue Gas

Boiler

Feedwater

Condensing

Economizer

450°F

Cond.

Tank

Make-Up

Water – 75%

Condensate

Return – 25%

180 °F

Process Steam

DA Steam

Make-Up

Water – 75%

50°F

190°F

100°F

72

Gas Savings Opportunity: Condensing Economizer (In-line)

DEAERATOR

8 psig

Stack Flue Gas

Boiler

Feedwater

Condensing

Economizer

450°F

Cond.

Tank

Make-Up

Water – 75%

Condensate

Return – 25%

180 °F

Process Steam

DA Steam

50°F

190°F

320°F

73

Gas Savings Opportunity: Feedwater Economizers (Offline)

DEAERATOR

8 psig

Stack Flue Gas

Boiler

Feedwater

Feedwater

Economizer

230°F

450°F

267°F

Condensing

Economizer

50°F

190°F

Make-Up

Water – 75%

New Stack

Cond.

Tank

Condensate

Return – 25%

180 °F

Process Steam

DA Steam

• Establish how much heat is available, Heat Source o Existing FW economizer, Flue gas temp., excess O2, steam production, gas

consumption, hours of operation, etc.

• Is there sufficient Heat Sink available?

o Boiler make-up water

o Domestic hot water

o Process water

• Heat sink temp must be low enough to bring FG temp below dew point (137 °F) to cause condensation

• Your ESC can help you evaluate your opportunity for a condensing economizer

74

Key Considerations



75

Example 6 : Installing an Inline Condensing Economizer

• 300BHP Boiler, 50% average loading, 6000hrs/yr, 75% Make-up

• Total Available Heat in Exhaust (no feedwater economizer):

1,145,417 BTU/hr ( > 50% Latent)

Parameter Savings

Average make-up water flow rate 7.4gpm (3,700lbs/hr)

Average Hourly Heat Recovery 554,825 BTU/hr






• Industries with steam boilers, requiring a large amount of hot water such as make-up, washing, process, DHW

• Best Candidates:

o Food and beverage

o Breweries

o Textile, commercial laundries

o Non-integrated paper mills

o Chemicals

o District heating

o Large hospitals

o Greenhouses

76

Typical Applications




• Stack Losses

• Blowdown Losses


77

Qng

Natural

Gas

Qsl

Stack Loss Qra

Radiation

Loss

Qst

Steam

Qbd

Blowdown

Loss

Qfw

Feedwater

78

Blowdown Heat Recovery

79




DEAERATOR

8 psig

Cond.

Tank

Make-Up

Water – 50%

Condensate

Return – 50%

180 °F

Natural Gas


Stack Flue Gas

Blowdown

DA Steam

Boiler

Feedwater

Blowdown loss can be reduced by:

1. Reducing amount of BD

• TDS Controller

2. Recovering BD heat

• Flash tank

• Heat exchanger

80

Gas Savings Opportunity: Blowdown (BD) Loss

Blowdown Heat Recovery

• Utilize energy in blowdown for:

– Generating flash steam for DA (or condensate receiver)

– Preheating make-up water

• Typically sold as skid type package

• Additional benefit – eliminates the need to use fresh water for “cooling” of blowdown liquid before going to drain

• 1.5%-3% average savings (fuel input)

81

To Drain

Flash Tank

Heat Exchanger

Flash Steam to DA or Receiver

Make-Up

Water – 50%

Blow Down

10 psig

• 300 BHP boiler with 50% make-up and 8% blowdown rate

82

To Drain

Flash Tank

Heat Exchanger

Flash Steam to DA or Receiver

Make-Up

Water – 50%

Example 7 : Installing a blowdown heat recovery package


Revised simple payback

period

1.3 years

Parameter Savings







• Boiler Basics



83


84

• Enbridge is offering industrial customers double the financial incentive towards an energy retrofit to your boiler system!

• That’s a maximum of $25,000 or 50% of the project cost!

• The incentive can be used towards linkageless controls, economizers and blow down heat recovery system

• See your ESC for details

Limited Double Incentive Boiler Campaign

A

limited

time

offer!

85

Example 5 : Installing a Feedwater Economizer

• 300BHP Boiler, 50% average loading, 6000hrs/yr

• Reduction of Flue Gas temperature from 450°F to 320°F

Parameter Savings







Limited time incentive $12,500


Summary

• Energy savings starts by understanding the need, then proceed upstream

• Boiler Savings:

– Target stack losses and blowdown losses

• Look at combustion efficiency

• Heat recovery

• Your ESC can help you better understand your boiler system and the savings opportunities

• Act now to take advantage of this limited time offer!

86

Knowledge

Development

Opportunity

Identification

Measurement Engineering

Analysis

Action and

Implementation

THANK YOU!

QUESTIONS?

87

Boiler Basics Workshop - For Homes - Enbridge Gas …€¦ · · 2014-12-01•Typical range is 3% – 6% of feedwater 37 . ... Test Boiler #1 Boiler #2 Feedwater Condensate Softener

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