trend setting approach
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Trend Setting Approach towards controllable Losses inSteam Generating System
By Sri Ansuman Sen Sharma; India Boiler dot Com
Introduction:
Steam generating system efficiency is defined as the heat added to the
working fluid expressed as a percentage of the heat in the fuel being burnt.Efficiency = Heat output in steam/ Heat Input through fuel. If someone does
this calculation and finds their boiler efficiency is to the tune of 85 to 88%, the
person quite naturally would be satisfied with the performance of their boiler
plant. In fact, it is quite often, one would tend to approximation in measuringperformance parameters in order to reach the efficiency figure of his/ her
preference.
This approach doesnt give any sort of idea about the performance nor does it
affect any change in actions to optimize performance of the system.When asked about the performance, some times you come across these
responses:
Our stack gas never looks black! In fact it looks a little whitish yellow. We are
very careful about supplying adequate air. We have Oxygen monitoring system; therefore our combustion must bepretty efficient!
Our stack temperature is 180oC, which is same as what other industries are
maintaining. We are using Natural Gas as fuel! We have an Economizer in line and therefore all waste heat is being
recovered
We have hundreds of steam traps in the steam distribution system. Hardly 4
to 5 are passing, which is less than even 0.5%!We have a large and complex steam distribution system. All steam pipes are
well insulated. Only few of the valve insulations are sometimes removed to
attend gland leakage (You know, Indian Steam Valves!). Since they frequently
leak, we keep them open to attend the leakage from time to time. However,its just a few valves!
Since we have a low pressure boiler, we are using softening plant for water
treatment..and so on.
With more focus on energy conservation these days, a number of technologieshave evolved and continues evolving, which can improve the performance
significantly. But if you are already satisfied with the performance of your
system, would you take the pain to introduce a new technology or change theexisting practice and risk rocking a steady ship? Therefore first we need to be
dissatisfied! As Sharukh Khan theatrically says in one of those Ads DONT
BE SANTUSHT!
Its not Heat .its Money!
The new trend setting approach is exactly that. Gone were the days, where
fuel bill was a necessary expenditure to achieve all important Production.And forget about passing on the fuel cost to the customers, because you
would be kicked out of the competition in that case. You will have to start
looking for the Controllable Losses and when you identify them, there are
lots of ways to plug them. One has to first change their approach towardsSteam Generating System.
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Performance of steam generator:
In order to achieve economic optimization in Boiler operation, one needs to
ensure maximum extraction of heat from the fuel and then transfer maximum
extracted heat to water and steam without causing any accident.Not all boilers are created equal each boiler system has its own specific
characteristics, be it a different design consideration, different fuels ordifferent operating conditions. Approach towards economic optimization
naturally differs from system to system.But the good thing is Every Boiler operates under the same fundamental
thermodynamic principles. If we take two Steam generating systems, one
with a capacity of 700 TPH steam at 510oC superheat and 110 bar pressureand another with a capacity of 8 TPH saturated steam at 12 bar pressure, the
fundamental for heat utilization remains same.Steam generating system efficiency to the greater extent depends on the skill
of designing but there is no fundamental reason for any difference in
efficiency between a high pressure and low pressure boiler. Large boilers
generally would be expected to be more efficient particularly due to designimprovements.
If we start looking for the controllable losses, if we can identify them, we can
definitely find means to stop them.
Change in outlook: Actuallythere are hundreds of areas, where we need tochange our outlook. However, for the sake of this discussion, let us consider
only those statements, I have mentioned earlier.
Statement #1
Our stack gas never looks black! In fact it looks a little whitish yellow. We are
very careful about supplying adequate air. Mind you; this kind of attitudelies with the operator of small and aged boilers, generally using lignite or
other solid fuel, firing manually most of the time, and guise what? They aremore in numbers in our country! The only priority for their operator is to
supply needed quantity of steam at required pressure to the user end. The
inlet Air Damper remains in 100% open condition all the time and at times, 80
150% excess air is being used. No wonder the smoke looks whitish yellow incolour! The owners, not the operators, in this case are required to change
their approach. This can be helped if some one uses a calculator and tell the
owner that even lowering the excess air just by 10% might lower the annualfuel cost by Rs. 60-70 Ks, even when you are using a cheap fuel like lignite.
Whereas, the scope is to lower down the excess air by nearly 40-50% in many
cases!Then perhaps they would start thinking about installing some combustion
control techniques. A little modification in the furnace and fuel feeding
methods can result into a lot of saving.
They may even start thinking about getting a new, more energy efficientBoiler all together! The mantra is. DONT BE SANTUSHT!
Statement #2
We have Oxygen monitoring system; therefore our combustion must be
pretty efficient! This is a slightly better scenario than the previous one.Here the intent of controlling excess air is present but the method of
application is doubtful in some cases. Simply installing a Combustion Control
unit by Oxygen Trimming may not achieve the desired control of excess air. In
most cases, when the process operator starts complaining about thetemperature drop (read pressure drop, since more steam is being drawn than
the boiler can produce), the poor operator at the boiler has no option other
than trying to get maximum..and the result? Inlet Damper in 100% open
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condition and to hell with what Oxygen meter is showing! In fact they are the
happiest when these Oxygen meters start giving faulty results (which they
eventually do) and then they are in no hurry to get it calibrated. In many
cases VFD is not installed, therefore losing in both combustion efficiency andfan power. In this case both the owner and the operator should be aware that
merely introducing Combustion Control Technology is not enough. You have toensure proper operation of the same. Just DONT BE SANTUSHT because
you have spent some money to ensure efficient combustion.
Statement #3
Our stack temperature is 180oC, which is same as what many otherindustries are maintaining. We are using Natural Gas as fuel! Now that is a
criminal waste of energy! When we can bring down that temperature to even100oC if possible and when lowering of 22oC can increase the efficiency by a
whopping 1%! One may not be able to change it that easily but at least one
should be always aware about it. If we keep in mind that there is a huge
amount of energy available, which can be recovered, we would be alwayslooking for the economically viable options to recover the same. There can be
so many options.installing an Economizer, installing an Air Heater, installing
a condensate heater, using the heat in an evaporative chiller, or one can eventhink of drying fuel by the hot gas. Till you get some solution to recover that
heat, just DONT BE SANTUSHT. See money going out of your chimneywhenever you look at the stack.
Statement #4
We have an Economizer in line and therefore all waste heat is being
recovered This is again a slightly better scenario than the previous one.Some thing has been done to recover the waste heat, therefore no one can
blame the intention but in many cases, the application is again doubtful. I willinterject with one of my personal experience here. One of the chemical
Industries, have asked us to review their system since they doubted the
adequacy of steam generation from one of their package type boilers. Their
stack temperature sometimes goes as high as 200-210oC. They are firingNatural Gas and sometimes FO. They also have an Economizer in line!
We came to know from the operators that the temperature pick up in the
economizer is around 5oC! Fortunately, during our visit, the Economizer wastaken off line because of a tube leakage and since repairing was going on, we
could get a look inside. What we found was the partition wall which was
designed to be there (it was there in the drawing alright!) to guide the hot fluegas across the tubes, was absent. The flue gas was going inside the
Economizer and short circuiting to the outlet without passing through the Eco-
tubes. The Economizer was practically serving the purpose of an ash collector
when they have been using FO (which was evident from the thick layer of ashcollected at the bottom). Now, this boiler was in operation for several years,
during which a number of times the Economizer was opened for tuberepairing. It never occurred to anyone that The Economizer is redundant, it is
not recovering any waste heat..why? Because everybody was
SANTUSHT, an Economizer was kept in line after all! This is a classical
example of the approach, which we are required to change.
Statement #5
We have hundreds of steam traps in the steam distribution system. Hardly 4to 5 are passing, which is less than even 0.5%! A definite understatement!
Much more than those numbers are likely to be in failed open condition. There
are very few organizations, which are seriously checking trap condition
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regularly. In most of the process industries, once the traps are fitted, since
they are self operated, they are usually forgotten. Particularly where
condensate is recovered through a closed cycle (which is of course
commendable), it becomes extremely difficult to identify a faulty trap. Itrequires a trained team of professional to identify a trap in failed open
condition. This is of course going to cost money, in fact, quite a lot of moneysince you are planning to replace a trap every time it is found faulty! Who is
willing to spend unnecessarily for such small things? Only large plants, whichare having large and complicated distribution system, may be able to afford
such expenditure.this could be the common reaction from most of the
small plant operators.Here is a simple variant of the Napier formula, which gives a pretty close
estimation of the Steam loss through an orifice.
Steam Flow (kg/ hr) W = 11x Pa x D
[Where Pa is Absolute Pressure, kg/cm2and D is diameter of Orifice in cm]
Formula for daily Fuel Cost per Trap - Using Cost of Natural Gas for steam
raising:
Q = W x 24 x h fg x C / (BE x CV)
Where: Q = Energy Lost per day in RupeesL = kg/Hr of steam lost
hfg = Latent heat of steam at corresponding pressure
C = Cost of fuel per sm3
BE = Boiler EfficiencyCV = Calorific Value in kcal/ sm3
When using some other fuel, CV and C are to be taken accordingly.Even if we consider a partially passing trap or valve or any other orifice, we
will see the cost of steam loss is reaching a staggering figure. Next time I see
a steam trap, I would start wonderingis it passing? I will see money
going down the drain (literally!) and I will not be SANTUSHT until I make
sure it is not.
Statement #6
We have a large and complex steam distribution system. All steam pipes are
well insulated. Only few of the valve insulations are sometimes removed toattend gland leakage (You know, Indian Steam Valves!). Since they frequently
leak, we keep them open to attend the leakage from time to time. However,
its just a few valves! That happens to be a fact! A steam line has to be
insulated and that is universally agreed. You ask whyand 8 out of 10answers would be Steam would get condensed, otherwise. There is
nothing wrong with the answer, but everything wrong with the approach.
Lets talk money.
The heat losses through bare pipes can be found by reference to Table given
by Spirax Sarco and using a simple equation. Against different temperature
difference, heat emission per meter of un-insulated pipe is to be taken fromthe below mentioned table. It is considered as heat emission from barehorizontal pipes with ambient temperatures between 10C and 20C and still
air conditions. The result may not be very accurate, but it would give a close
estimation of the actual loss taking place.
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Table 1
Pipe size (NB)
15 20 25 32 40 50 65 80 100 150
Temperature
difference
steam to airC W/ m
60 60 72 88 111 125 145 172 210 250 351
70 72 87 106 132 147 177 209 253 311 43280 86 104 125 155 171 212 248 298 376 519
90 100 121 146 180 196 248 291 347 443 610
100 116 140 169 207 223 287 336 400 514 706
110 132 160 193 237 251 328 385 457 587 807
120 149 181 219 268 282 371 436 517 664 914
130 168 203 247 301 313 417 490 581 743 1025
140 187 226 276 337 347 464 547 649 825 1142
150 208 250 306 374 382 514 607 720 911 1263
160 229 276 338 413 418 566 670 794 999 1390
170 251 302 372 455 457 620 736 873 1090 1521
180 275 330 407 499 497 676 805 955 1184 1658190 299 359 444 544 538 735 877 1041 1281 1800
200 325 389 483 592 582 795 951 1130 1381 1947
Using the temperature difference of the steam and atmosphere, it can be
converted as
Fuel cost per meter length per day of bare pipe =
HL (from the table) x 3.6 x 4.187 x 24 x C/ (BE x CV)
Even if we neglect the loss due to condensate, this would sum up to a
considerable amount if we use a calculator.
Next time, when we see an un-insulated steam pipe, we would not think ofsteam condensation, we will see MONEY DOWN THE DRAIN.
Here is an interesting piece of information. It is not only important to insulatethe bare pipe but all hot parts of the system with the exception of safety
valves should be insulated. This includes all flanged joints on the mains, and
also the valves and other fittings.
Equivalent lengths of pipe for valves and fittings can be taken as:
Pair o f mating flanges - 0.5 m Line size valve - 1.0 m
So if we have 4 or 5 line size valves un-insulated, those should be counted as4-5 m of bare pipe. We can not just wait for the annual turnaround to attend
the miscellaneous insulation jobs. As prefabricated insulating covers for
flanged joints and valves are now more widely available the loss by keepingthese parts un-insulated for maintenance point of view can be avoided. These
are usually provided with fasteners so that they can readily be detached to
provide access for maintenance purposes.
Effect of moisture
Insulation primarily depends on air-filled voids to function effectively.Exposure to moisture causes the displacement of insulating air by heat-
conducting water. Waterlogged insulation transfers heat 15-20 times faster
than dry insulation! Protecting insulation from moisture/water ingress is just
as important as selecting the most effective type of insulation and installing
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an economic thickness. The practical requirement, then, is to make
waterproofing an integral part of any insulating job.
Install adequate, leak-proof vapour barriers on the interior (warm) sideof walls, ceilings or floors.
Weatherproof exterior walls by cladding or other treatment thatprevents water infiltration.
Maintain the integrity of water-impervious roof membrane by regularinspection and maintenance.
Cover insulated pipes with suitable cladding (whether for indoor oroutdoor applications) with sealed joints, and maintain its integrity byinspection and prompt repair of damaged sections.
For high-temperature applications, choose a vapour-permeablecovering that will allow moisture to pass outward.
Statement #7
Since we have a low pressure boiler, we are using softening plant for water
treatment What is wrong in this statement? Apparently nothing, because a
good softening plant should be enough for a low pressure boiler, so far as
water quality control is concerned.Does a softening reduce TDS? The answer is No.Does the use of soft water reduce Blow Down? The answer is still No.
Does Blow Down affect efficiency? The answer is still No! Why? Because most
standards for computation of boiler efficiency, including IS 8753 and BS845 do
not include blow down as a loss in the efficiency determinationprocess.. and we areSANTUSHT!
Should we?
In a small boiler plant usually there is no flush steam recovery system and
here the cost of fuel loss comes toBw x (hg h) x 24 x C/ (BE x CV)
Where,Bw = Blow down quantity per hour
hg = Enthalpy of 1 kg of saturated steam produced under working pressure,
h = Enthalpy of 1 kg of feed water entering the boiler.
And Bw can be calculated as (considering no condensate return)Bw=(Generation in kg per hour x Feed Water TDS) / (permissible TDS in
Boiler Water Feed Water TDS)
if we consider use of return condensate as Feed water with some % age of
make up water from the softening plant, the blow down rate will decrease andwe can work it out from simple material balance.
It is evident that if we can keep the Feed water TDS as minimum as possible,
the required rate of Blow down will decrease. Though the permissible TDS in
Boiler Water is quite high for low pressure boilers (3500 5000 ppm), still the
blow down requirement would be considerably high. Usually once a shift blowdown is the most common practice in many boiler plants.Where as, a small RO plant or a DM plant is not costing very high these days.
Why dont we check out? The Mantra is once againplease DONT BE
SANTUSHT!
Conclusion:Energy Management is not a job for a designated group of professionals givenwith the responsibility to increase efficiency. When every individual handling
energy starts looking for holes to plug the controllable losses, there would be
tangible result. Therefore the trend setting approach for every operators of a
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steam generating system would be See money while seeing fuel, or
stack gas, or steam.. always try to identify the controllable losses. and
never, ever be SANTUSHT with the existing practice