Post on 26-Feb-2018
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DISSOLVED
GAS ANALYSISFOR THE SMART GRIDAND FOR THE FUTURE
AWAKENING YOUR 6 thSENSE
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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
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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
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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
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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
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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
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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
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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
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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
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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.
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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
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SmartDGASystem Diagram
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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
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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
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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.
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UNDERSTAND05
IMPLEMENT
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ANALYZE
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DESIGN
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SUSTAIN
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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
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info@lumasenseinc.comLumaSense Technologies, Inc., reserves the right to change
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