dga ebook web

7/25/2019 DGA eBook Web

1/16

DISSOLVED

GAS ANALYSISFOR THE SMART GRIDAND FOR THE FUTURE

AWAKENING YOUR 6 thSENSE


2/16

GlobalEnergy

IndustrialMaterials

AdvancedTechnologies

LumaSense Global Energy customers

include the worlds leading power

producers and energy transmitters

such as electrical utilities as well as

oil/gas refineries.

LumaSense Industrial Materials cus-

tomers include the worlds leading

manufacturers of glass, metals, and

plastics.

LumaSense Advanced Technologies

customers include the worlds lead-

ing semiconductor, solar, and LED/

MOCVD equipment manufacturers.

2007

Acquires Andros,

Impac and Mikron.

2010

Acquires Opsens

Energy and ITC

2011

Acquires Reliability

Point for Service

Offerings

2012

LS6Systems at

50,000+ sites, First

SmartDGA for

Energy Launched

1958

Impacis

founded

1969

Andros and

Mikron are

founded

1978

Luxtron and

Innova are

founded

2005

LumaSense is

founded and

acquires Luxtron

2006

Acquires Innova

CORPORAE HISORY

OUR FOCUS MARKES

VISION

MISSION

To give our customers a competitive edge by awakening their6thsense

To provide insight and information to help our customersreduce waste and inefficiency in their most resource-intensive

processes


3/16

Current rends for Smart Grid Investment

Global Energy Usage

Large Investments in New Assets RequiringSmart Instrumentation

Investment will be needed in Online DGA for new Transformers/LTC's and to extend life of existing Transformers/LTC's

$732B Investment Gap by 2040 Will Exist -Existing Assets Will Need Smart Instrumentation

Over $2 Trillion in capital investments over the next

20 years.

Annual Smart Grid spending is expected to reach$65 Billion by 2017

By 2017, $278 Billion will have been invested in T&Dinfrastructure, with only $48 Billion in Smart Meters

+

National Electricity Infrastructure Gap:Estimated at $732 Billion by 2040

(in billions of 2010 dollars)

Type of InfrastructureCumulative

2020 2040

Generation 12.3 401.1

Transmission 37.3 111.8

Distribution 57.4 219

U.S. Total 107 731.8

Source: ASCE

Did you Know:

65% of global warming pollution is

estimated to come from energy generation

and usage

$25 billion is paid by consumers everyyear for electricity estimated to be lost to

inefficient transmission and distribution

in the United States

$150 billion is lost every year due to

power outages and blackouts in the United

States alone

$108 billion is spent each year on energy

bills for commercial buildings in the

United States

30% of energy used by commercial

buildings could be cut through investmentsin energy efficiency

1990 2000 2008 2015 2020 2025 2030 2035

800

600

400

200

0

354

406

505

573619

671721

770Figure 1.

World energy

consumption,

1990-2035(quadrillion Btu)

Non-OECD

OECD

The electric grid is the vast network

of transmission lines, substations and

power plants that deliver electric

power to our homes and businesses. It

is one of the great engineering feats

of the 20thcentury, and includes more

than 9,000 generating plants and

around 300,000 miles of transmission

lines in the U.S.

But the current grid is inefficient, and

has changed little in concept since

the days of Thomas Edison. Up to ten

percent of the power we generate

is lost in transmission. Many power

plants, often the dirtiest, are held in

reservealthough still running and

pollutingand used only to generate

power several dozen hours per year.

This costs consumers money and

means unnecessary pollution from

power plants.

A "smart" electric grid allows homes

and businesses to use, as well as

produce and sell, electricity in a more

technologically advanced way. We

are about to spend $1.5 trillion to

upgrade and expand the electric grid

in the United States over the next 25

years.

This will result in:

30% cut in global warming pollutionfrom the electric sector with a full

deployment of smart grid technology

25% cut in global warming pollutionfrom transportation with a fullydeployed smart grid


4/16

Te ransformer Dilemma

Over the past several decades, the

expansion of power consumption has

been unprecedented globally with the

additions of several transformers to

the expanding global grid. Significant

industrial growth happened in

the 1950s and beyond. Power

consumption continues to grow on

the average 3-5% per year globally.

According to the U.S. Commerce

Department, transformer installations

in the United States reached their

peak in 1974 but have decreased

over subsequent years. The average

age of a power transformer is 30-40

years, which means many of these

transformers are now at the end of

their life.

In a 1975 study, it was found that the

average age at the time of a power

transformer failure was 9.4 years.

In a 1985 study by Hartford Steam

Boiler, it was found to be 11.4 years.

Transformers fail for various reasons

before their expected life, and those

that make it to 40 years survive on

borrowed time beyond that point.

Failure Distribution (50% rate)(all vintages, assuming no replacements)

Transformer Failure Rate Functions

Transformer Failure Rate vs. TimeInsulation Stress vs. Strength

35.00

30.00

25.00

20.00

15.00

10.00

5.00

0.00

Hazard

Function

100%

90%

80%

70%

60%

50%

40%

30%

20%

10%

0%

1964

1967

1969

1971

1973

1975

1977

1979

1981

1983

1985

1987

1989

1991

1993

1995

1997

1999

2001

2003

2005

2007

2009

2011

2013

2015 0 10 20 30 40 50 60 70 80 90 100

Failure

New Increasing Age Old

IncidentsInsulationStress

InsulationSpare

Margin

Insulation Strength Reducing Strength withtime and after incidents

FailureRate

Time

Years

Observed FailureRate

DecreasingFailureRate

ConstantFailureRate

IncreasingFailureRate

Constant (Random)Failures

EarlyInfant

Mortality Failure

Wear-outFailures


5/16

What is DGA? Why is it important?

Currently, less than 5 percent of transformers have condition-based online DGA monitoring systems, according to industry

sources, and approximately 30 percent of all transformer failures in the United States are related to faulty LTCs.

Widespread condition monitoring was unattainable using traditional technologies, largely due to high costs and excessive

installation time. Whereas other systems take days to install, a SmartDGA monitor can be installed in a matter of hours.

Additionally, SmartDGA monitors will cost up to 50-percent less than other monitors. The first monitor in the new line,

the SmartDGA Gauge, will be the industrys first dedicated online gas monitor for LTCs.

Recent Survey Results

ONLINE DGA SURVEY RESULTS 1

0.0%

5.0%

10.0%

15.0%

20.0%

25.0%

30.0%

35.0%

40.0%

45.0%

0-10%10-15%

15-25%25-40%

40-50%Over

50%

44.4%

22.8%

16.0%

6.2%

3.1%7.4%

83.2%of

respondentsm

onitor

25%orlessw

ith

OnlineDGA

ONLINEDGA SURVEY RESULTS 9

75.0%

43.2%

30.1%

68.8%

48.9%

40.9%

34.7%

14.8%

15.9%

47.7%

Hydrogen

Carbon Monoxide

Carbon Dioxide

Acetylene

Ethylene

Methane

Ethane

Oxygen

Nitrogen

Moisture

ONLINEDGA SURVEY RESULTS 11

0%

5%

10%

15%

20%

25%

30%

Under

25

Years

25-30

Years30-35

Years35-40

Years40-45

Years45-50

YearsOver 50

Years

27%29%

23%

13%

7.40%

0% 0.80%

Over a period of 3 months in 2012, LumaSense Technologies conducted a global survey relating to online Dissolved Gas

Analysis and Transformer Monitoring. The survey was implemented via online, written, and verbal interviews. The follow-

ing charts highlight a few key points from the survey.

Benefits of Online DGA vs Offline DGA

DGA is the single most comprehensive

and widely accepted tool for trans-

former condition assessment. Today,

it is mostly done annually or twice a

year with manual samples offline and

takes one to two weeks for results.

The transition from offline to online

monitoring is driven by the need for

real-time data to support aging and

stressed assets.

Online DGA helps utilities to:

Obtain real-time data for real-timeactions

Avoid unplanned failures

Tempering

Adopt lower cost condition basedmaintenance

Defer capital expenditures by

extending the transformer's usefullife

Average Age of ransformers on

ransmission System

Critical Gases/Readings to Monitor Percent of ransformers with Online

DGA Monitoring

25%

12%

13%

11%

6%

6%

3%2%

Lightning

Through Faults

Insulation Deterioration

Inadequate Maintenance

Moisture

Loose Connections

Workmanship

Overloading

All Others

Transformer Failure Methods

22%

Chart Source: William H. Bartley, P.E.The Hartford Steam Boiler Inspection and Insurance Co.

%ofTransformersMonitored

% ofRespondents


6/16

echnology Overview

Factors to Consider When Selecting Online DGA

69.5%

54.6%

26.4%

28.7%

47.7%

37.4%

21.8%

43.1%

32.2%

22.4%

27.0%

29.9%

2.4%

18.4%

55.7%

Price

Technology Used

Operating Temperature Limits

System Ruggedness

Accuracy

Repeatability

Reputation of Supplier

Maintenance Required (consumables)

Warranty

Communication Protocols UsedData Storage

Ease of Installation

Diagnostics/Analysis Software Available

Lead Time

On site service and supportDuring a 2012 LumaSense Technologies

Global Survey, respondents indicated the

following factors were important to

consider when selecting online DGAmonitoring solutions.

IEEE Std. C57.104-2008 IEEE Guide for the interpretation of Gases Generated in OilImmersed ransformers

IEEE Std. C57.139.2010 IEEE Guide for Dissolved Gas Analysis in ransformer Load apChangers

IEEE Std. C57.12.80-2002 erminology for Power and Distribution ransformers

IEC 60599-2007-05 Edition 2.1 Mineral Oil Impregnated Electrical Equipment in Service Guide tothe Interpretation of Dissolved and Free Gas Analysis

Standards and Guidelines Governing DGA

Technology Advantages Disadvantages Accuracy Cost

NDIRNon-DispersiveInfrared

Simultaneous multi-gas measurement No required calibrations Low maintenance Fast gas measurement time

High ease of use and install

Limited ability to detect very low gas concentra-tions

Interfering gases can effect accuracy; howevertypically can be compensated

Medium Low

NIRNear Infrared

Simultaneous multi-gas measurement Non-frequent calibrations Low maintenance Easily installed

Limited ability to measure high gas concentrations Can be impacted by interfering gases

Low Medium

GCGas Chromatography

Able to measure many different gases Based on standards in many utility labs

Frequent calibrations needed Auxiliary (carrier) gas needed maintenance cost Can be difficult to install

Medium High

PASPhotoacoustic Spec-troscopy

Can detect/measure very low (ppm andppb) gas concentrations

Low maintenance based on systemfilters that are used

Limited ability to measure high gas concentrations Interfering gases can effect accuracy; however

typically can be compensated Affected by vibration Can be difficult to install

High High

Electrochemical Small size

Good for measuring gases that canteasily or inexpensively be measured byother technologies

Frequent calibrations needed

Short/limited life time needs replacement Single gas measurement Low Low


7/16

INDICATION / FAULT GAS H2

CO CO2

CH4

C2H

2C

2H

4C

2H

6O

2H

2O

Cellulose aging

Mineral oil decomposition

Leaks in oil expansion systems, gaskets, welds, etc.

Thermal faults Cellulose

Thermal faults in Oil @ 150C - 300C Trace

Thermal faults in Oil @ 300C - 700C

Trace

Thermal faults in Oil @ >700C

Partial Discharge

Trace

Arcing

Indication/Fault Gas Table

Combustible gas generation vs. approximate oildecomposition temperature

Temperature (C)Gas generation (not to scale)Approximate oil decomposition temperature >150C

Partial discharge (not temperature dependent)Range of normal operation

0 40 80160C

250C

200C

300C

350C

600C

700C

500C

65C

1.8

1.4

1.0

0.6

0.2

Hydrogen

(H2)

Methane

(CH4)

Ethane

(C2H

6)

Ethylene

(C2H

4)

Acetylene

(C2H

2)

C2H

4>CH

4

CH4>H

2

Hot spots

(of increasingtemperature)

Arcing

Conditions

C2H

4>C

2H

6Trace

C2H

2>10% of C

2H

4

H2(+79%)

C2

H2and CO2

CH4

C2H

4

C2H

6

(-66%)

N2

CO

O2

The diagnostic theories based upon

the thermal degradation principles

employ an array of ratios of certain

key combustible gases as the fault

type indicators. These five ratios are:

Ratio 1 (R1) = CH4/H

2

Ratio 2 (R2) = C2H

2/C

2H

4

Ratio 3 (R3) = C2H

2/CH

4

Ratio 4 (R4) = C2H

6/C

2H

2

Ratio 5 (R5) = C2H4/C2H6

The first ratio method (Doernenburg)

utilizes Ratios 1, 2, 3, and 4. This

procedure requires significant levels

of the gases to be present in order for

the diagnosis to be valid.

The second method (Rogers) utilizes

Ratios 1, 2, and 5. The Rogers method

does not depend on specific gas con-

centrations to exist in the transformer

for the diagnosis to be valid. However,

it suggests that the method be used

only when the normal limits of the

individual gases have been exceeded.

Gas Ratio Analysis


8/16

This method utilizes the gas concen-

tration from ratio of CH4/H

2, C

2H

2/CH

4,

C2H

4/C

2H

6, and C

2H

2/C

2H

4. The value

of the gases at first, must exceed the

concentration L1 (2 times limit for one

of following: H2, CH

4, C

2H

2and C

2H

4

and one times limit for CO or C2H

6)

to ascertain whether there is really

a problem with the unit and then

whether there is sufficient generation

of each gas for the ratio analysis to be

applicable.

Doernenburg Ratios Method (IEEE Std. C57.104-2008)

Oil Gas space Oil Gas space Oil Gas space Oil Gas space

1. Thermal decomposition >1.0 >0.1 0.1


9/16

KEY GAS FAULT TYPE TYPICAL PROPORTIONS OF GENERATED COMBUSTIBLE GASES

C2H

4Thermal oil Mainly C

2H

4; Smaller proportions of C

2H

6, CH

4, and H

2; Traces of C

2H

2at

very high fault temperatures

CO Thermal oil and cellulose Mainly CO; Much smaller quantities of hydrocarbon; gases in same pro-portions as thermal faults in oil alone.

H2 Electrical Low Energy PartialDiscarge Mainly H2; Small quantities of CH4; Traces of C2H4and C2H6

H2& C

2H

2Electrical High Energy (arcing) Mainly H

2and C

2H

2; Minor traces of CH

4, C

2H

4, and C

2H

6; Also CO if cel-

lulose is involved

Key Gas Method (IEEE Std. C57.104-2008)

TDCG levels(ppm)

TDGC rate(ppm/day)

Sampling intervals and operating procedures for gas generation rates

Sampling Interval Operating procedures

Condition 4 >4630 >30 Daily Consider removal from service

Advise manufacturer10 to 30 Daily30 Weekly Exercise extreme caution; Analyze for individualgasesPlan outageAdvise manufacturer

10 to 30 Weekly

30 Monthly Exercise extreme caution; Analyze for individualgasesDetermine load dependence

10 to 30 Monthly

30 Monthly Exercise caution; Analyze for individual gases;Determine load dependence

10 to 30 Quarterly Continue normal operation


10/16

C2H

2/H

2Ratio (IEC 60599-2007-05)

In power transformers, on load tap changer (OLTC) operations produce gases

corresponding to discharges of low energy. If some oil or gas communication is

possible between the OLTC compartment and the main tank, or between the

respective conservators, these gases may contaminate the oil in the main tank

and lead to a wrong diagnoses.

C2H

2/H

2ratios higher than 2 to 3 in the main tank are thus considered as an indication of OLTC contamination. This can

be confirmed by comparing DGA results in the main tank, in the OLTC and in the conservators. The values of the gas ratio

and of the acetylene concentration depend on the number of OLTC operations and on the way the contamination has

occurred (through the oil or the gas).

A C2H

2/H

2ratio two to three times the

level in the main tank indicates possibleOLC contamination.

D1 D2 DT T3

80 60 40 20

60

60

80

80

PD

T1

T2

40

40

20

20

CH4

[%]

C2H

4[%]

C2H

2[%]

Duval Triangle (IEC 60599-2007-05)

ZONE INDICATION

T1 Thermal fault 300C

T2 Thermal fault >300C, 700C

T3 Thermal fault >700C

D1 Discharges of low-energy

D2 Discharges of high-energy

DT Combination of thermal faults anddischarges

PD Partial discharge

Sections within the triangle designate:This method uses three ratios to locatethe point within the triangle.

%CH4= (CH

4/CH

4+C

2H

4+C

2H

2) x 100

%C2H

4= (C

2H

4/CH

4+C

2H

4+C

2H

2) x 100

%C2H

2= (C

2H

2/CH

4+C

2H

4+C

2H

2) x 100

Basic Gas Ratio (IEC 60599-2007-05)

10

1.0

0.1

10

1.0

0.1

1.0

10

1.0

1.00.1

0.1

0.1

X

Y

Z

C2H

2

C2H

4

C2H

4

C2H

6

CH4

H2

D1/D2

PD

T1

CASE CHARACTERISTIC FAULT C2H

2

C2H

4

CH4

H2

C2H

4

C2H

6

PD Partial discharges NS 1

D2 Discharges of high energy 0.6 - 2.5 0.1 - 1 >2T1 Thermal fault

t < 300CNS >1 but

NS4

2013 LumaSense Technologies,Inc. All Rights Reserved.LumaSense, SmartDGA, EZHub, and LumaSmart are trademarksof LumaSense Technologies, Inc.

Note: Te LumaNostics software

includes the various Duval triangles

for LC's, Mineral Oil and

other oils presently being used intransformers.


11/16

Learn More about our SmartDGASolution

SmartDGABenefits: No consumables, carrier gas, regular

maintenance, or calibration needed

Flexible grouping of products -dedicated LTC (Gauge), early warning(Guard), and full analysis (Guide)

Easy installation (2-4 man hours) withflexible installations (flow through,single valve, and two valve)

Up to 1/2 the purchase price ofcompetition, up to 1/5 total cost ofownership

Unique features in software,commissioning, viewing of data anddiagnostics of results

Technical Features:

3 Gas (C2H

2, C

2H

4, CH

4*)

LTC Condition Monitor4 Gas (H

2, CO, CO

2*, C

2H

2)

+ Moisture TransformerGas Monitor

9 Gas (H2, CO, C

2H

2, C

2H

4, CH

4,

CO2, C

2H

6, O

2, N

2) + Moisture

Transformer Gas Monitor

Specifications SmartDGA Gauge SmartDGA Guard SmartDGA Guide

Gas Measurements(gas in oil), gas ranges are

user configurable

Acetylene (C2H

2)

Ethylene (C2H

4)

Methane (CH4)

Moisture (RS):

Hydrogen (H2):

Carbon Monoxide (CO):

Carbon Dioxide (CO2):

Methane (CH4):

Ethane (C2H

6):

Oxygen (O2):

Nitrogen (N2):

MinMax

5050,000 ppm

5050,000 ppm

5050,000 ppm

199%

MinMax

0.510,000 ppm

199%

510,000 ppm

1010,000 ppm

1020,000 ppm*

MinMax

0.510,000 ppm

250,000 ppm

199 %

510,000 ppm

1010,000 ppm

1020,000 ppm

250,000 ppm

220,000 ppm

10050,000 ppm

5,000100,000 ppm

Gas Repeatability 5% or LDL, whichever is greater 5% or LDL, whichever is greater 5 % or LDL, whichever is greater

Sampling Time Every 24 hours - default,user selectable from approximately2.5 hours to 7 days. Sampling timeis progressive based on alarm condi-tions.

Every 24 hours - default,user selectable from from ap-proximately 2.5 hours to 7 days.Sampling time is progressive basedon alarm condition.

Every 24 hours - default,user selectable from approximately2.5 hours to 7 days. Sampling timeis progressive based on alarm condi-tion.

Moisture Accuracy 3 ppm or 2 % RS 3 ppm or 2 % RS 3 ppm or 2 % RS

Automatic ScheduleAcceleration

When user configurable Rate ofChange (ROC) levels and ratio(C

2H

4/C

2H

2) limits are exceeded

When user configured rate ofchange (ROC) levels are exceeded

When user configured rate of change(ROC) levels are exceeded

Installation Method Preferred mounting is in line withfiltration system

Mount horizontal and vertical; di-rect installation in oil phase throughdrain valve of transformer main

tank (single valve or dual valve)

Mount horizontal and vertical; directinstallation in oil phase throughdrain valve of transformer main tank

(single valve or dual valve)*Available January 2014


12/16

SmartDGASystem Diagram


13/16

SmartDGA EZHub Power, memory storage and communication hub for SmartDGA monitors

LumaSMART iCore Local display along with enhanced memory storage and communications

DGA Viewersoftware Software to enable easy commissioning and local display of online DGA results

SmartDGA Diagnostics Software* Display comprehensive analytics, graphics, and trending such as Duvals Triangle,

Rogers Ratios, Key Gases, and other tools.

SmartDGAAccessories

EZHub LumaSMAR iCore

Supplier Landscape

Instru

mentCost

>$60K

$50K

$40K

$30K

$20K

$10K

$5K

0

Performance/Features

Gaugefor LTC

H2only, $3-5k

Serveron TM1, Qualitrol 150

Tap Trans(for LTC), $70K

GE GLA 100, $3k

Delphi,$12K Calisto2,

$15K

Calisto9,$45K

TM3, $21KMiniTrans,

$25K

Transfix,$55K

MTE 1008$40K

MTE 1005$20K

MTE 1003$12K

MTE 1001$6K

TM8, $50K

Hydran M2with models,$15K

Guard

Guide

COMPREHENSIVEDGA MONITORS

SMOKE ALARMS

EARLY WARNINGDGA MONITORS

*Available April 2014


14/16

Winding hot spot temperatures are one of the most critical transformer meas-

urements. Hot spots are the highest temperature area in the transformer based

on flux leakage from the windings which can degrade the insulating paper

making the transformer susceptible to failure. Since transformer life is depend-

ent on the insulating paper, accurately monitoring over-temperature conditions

is critical.

Fiber optic monitoring enables true hot spot measurement by sensing

temperature directly in the windings. LumaSenses LUXTRONbrand offers

energy and utility companies two solutions:

LumaSMART Fluoroptic-based temperature solution for EHV/UHV/HVDCtransformers, large power transformers, and reactors; and

LumaSHIELD GaAs-based temperature solution for transmission and distri-

bution transformers.

echnologies for ransmission & Distribution

Winding Hot Spot Temperature Measurement

SmartDGA is the industrys most cost-effective Dissolved Gas Analysis (DGA)

solution, based on proven, state-of-the-art non-dispersive infrared (NDIR) tech-

nology. This suite of products is designed to allow customers to continuously

monitor and control the condition of LTCs and transformers.

SmartDGA offerings include the following:

SmartDGA Gauge Online 3 gas + moisture*Load Tap Changer DGA monitor

SmartDGA Guard Online 4 gas + moisture*DGA monitor for transformers

SmartDGA Guide Online 9 gas + moisture DGA monitor for transformers

SmartDGA EZHub Power and Communication Hub for SmartDGA monitors

LumaSMART iCore Local display along with enhanced memory storage andcommunications

DGA Viewer software - Software to enable easy setup and interpretation ofonline DGA results

SmartDGA Diagnostics Software** Display comprehensive analytics, graphics

and trending such as Duvals Triangle, Rogers Ratios, Key Gases, and other

tools

*Available January 2014**Available April 2014

Online DGA Monitoring for Load Tap Changers and Transformers

The SF6Leak Detector 3434i from LumaSense Technologies offers unmatched

performance and convenience. Based on Photoacoustic Spectroscopy (PAS)

technology, the system offers highly accurate, reliable, and stable quantitative

gas detection.

The growing environmental requirements regarding the use of SF6make

LumaSenses system a coveted tool designed for everyday use.

SF6Monitoring

SF6 Leak Detector 3434i

LumaSMAR

LumaSHIELD

SmartDGA Guide

EZHub


15/16

TermalSpection

724 DV

BoilerSpection HD/SD

LumaSpection TS724DV (ThermalSpection 724 Dual Vision) is an automated,

continuous thermal and visual imaging system used to identify thermal abnor-

malities within electrical substations and other process control systems. It offers

remote monitoring of temperatures in real-time via image data obtained from

one or more cameras and sent to a single central controller.

This LumaSpection system for substations can combine multiple technologies,

including fixed cameras, pan and tilt cameras, and pyrometry for the most cost

effective and comprehensive solution.

LumaSpection TS724DV for Substations

LumaSpection for Boilers

Infrared Detection Systems for Sulfur Recovery Units

and Flare Stack Monitoring

BoilerSpection MB

E Pulsar III

BoilerSpection IM

E Quasar M8100

With BoilerSpection, coal plant operators can proactively manage their boilers

by gaining visibility on scale buildup directly on the boiler tubes. Return on

investment (ROI) studies by customers have found ROIs measured in only a few

months, not years.

The challenge every coal plant owner or operator faces is to generate the

maximum amount of energy with the lowest emissions in the safest and most

economical way. Currently, coal plant operators use a number of ways to clean

boiler tubes but have inadequate methods to measure their effectiveness and

many have negative impacts such as prolonged downtime and thermal stress to

the boiler tubes.

BoilerSpection HD/SDBoilerSpection is a revolutionary thermal imaging system with the ability tosee through flames that helps coal plants run more efficiently, extract more

energy from their coal, and increase productivity.

BoilerSpection MB/IMThe BoilerSpection MB/IM systems are both portable solutions with the MBsystem providing radiometric readings and the IM system non-radiometricreadings. These easy-to-use mobile imaging solutions can be used forboilers and furnaces, and include all the components necessary for a userto be recording images in only minutes. Operators can then direct cleaningoperations, regulate flow of fuel and air, reduce emissions, reduce fuelconsumption and speed up boiler start up.

Thermometry for Sulfur RecoveryLumaSenses ET Pulsar family of detection systems are designed forcontinuous and instantaneous measurement of Refractory Temperature (RT),Gas Temperature (GT) or Integrated Temperature (FF) in the vessel away fromthe heat, vibration, and corrosive gases.

Infrared Flare Stack Detection SystemsLumaSenses ET Quasar family of detection systems are built for continuousduty monitoring of pilot flame (PM), flared gases (FM), and smoke particulate(SM) from flare stacks.


16/16

01

UNDERSTAND05

IMPLEMENT

02

ANALYZE

03

DESIGN

06

SUSTAIN

04

VALIDATE

WHA IS HE 6HSENSE?

Te 6thSense is the power of perception beyond the five senses. Some refer to it as intuition, others

say it is the ability to understand the subtle cause and effect relationship behind many events.

LumaSense echnologies provides the sensors and solutions that awaken this 6thSense in customersto allow them to efficiently optimize their processes.

Americas and Australia

HeadquartersSanta Clara, CAPh: +1 800 631 0176Fax: +1 408 727 1677

Europe, Middle East, Africa

Sales & Support CentersFrankfurt, GermanyPh: +49 69 97373 0Fax: +49 69 97373 167

India

Sales & Support CenterMumbai, IndiaPh: +91 22 67419203Fax: +91 22 67419201

ChinaSales & Support CenterShanghai, China

Ph: +86 133 1182 7766

Fax: +86 21 5877 2383

BrazilSales & Support CenterCampinas, BrasilPh: +55 19 3367 6533Fax: +55 19 3367 6533

www.lumasenseinc.com2013 LumaSense Technologies Inc All rights reserved

[email protected] Technologies, Inc., reserves the right to change

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