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The dosage rate is dependent on bioler operating condition, feed 2-3 ltrs of RXSOL-42-5001-025 solution for per thousand ltr of bioler water then control the system by periodic Alkalinity test procedure. If p-Alkalinity is below 200 ppm increase the ratio of RXSOL BWT 5001 solution. If p-Alkalinity is above 400 ppm reduce the concentration of RXSOL-42-5001-025 solution by dilution with water. RXSOL-42-5001-025 is strongly alkaline.RXSOL-42-5001-025 is best applied heat or diluted with any convenient strength on a continuous basis using a suitable chemicals pump. The product should be applied to the boiler feed tank or feed line to ensure adequate mixing.
Control is by simple boiler water tests or RX CLEANSERS can provide a suitable test kits for this purpose.
Used in low pressure and auxillary boilers
:::::::::::::::::::::Alkalinity TEST FOR BOILER & COOLING WATER ::::::::::::::::::::::::
REAGENT & APPARATUS :
Reagent: RXSOL TK 7 , TK 8 , TK 9 , . Apparatus : TEST TUBE , Titrator or DROPPER
PROCEDURE for p-ALKALINITY test ( STEP WISE ):
RESULT : Each DROPS is equivalent to 25 PPM of Alkalinity .
NOTE : p-Alkalinity VALUE = 25 X ( Total Number of DROPS of TK9 , during 3rdstep )
PROCEDURE for p-ALKALINITY & TOTAL ALKALINITY ( STEP WISE ):
RESULT : Each DROPS is equivalent to 25 PPM of Alkalinity .
NOTE : p-Alkalinity ppm CaCO3VALUE ( A ) = 25 X ( Total Number of DROPS of TK9 , during 3rdstep )
Total Alkalinity ppm CaCO3VALUE = A + { 25 X ( Total Number of DROPS of TK9 , during 5th step )}
|
NUMBER OF DROPS OF TK9 p-Alkalinity as CaCO3
1 >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>25
3 >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>> 75
5 >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>> > 125
20 >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>> > 500
40 >>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>>> 1000
Optimum Result : p-Alkalinity level is between 100 to 150 PPM is suggested. For Below 50 ppm , Dose ½ Ltrs of RXSOL-50-5001-025 for 1000 Ltrs of BOILER WATER , to maintain p-Alkalinity level 100 ppm. Refill pack : REPLACEMENTS TK7 : ECONOMIC PACK ( 100 / 200 / 500 ml ) available TK8 : ECONOMIC PACK ( 100 / 200 / 500 ml ) available TK9 : ECONOMIC PACK ( 100 / 200 / 500 ml ) available |
BOILER WATER TREATMENT chemicals manufacturer and supplier in INDIA, MUSCAT OMAN, UAE DUBAI, Nairobi
RXSOL-42-5001-025 Boiler Water treatment specialized is a well - balanced blend for boiler water treatment products, Resulting Multi Functional Boiler Treatment including scale and corrosion control by one shot operation. A one-step treatment to control the formation of rust and scale in low pressure and auxillary boilers with working pressure up to 20 bars.
The stability of the added polymers are very useful for water treatment processes. Such polymers with low molecular weights cannot only inhibit calcium, magnesium, and silica scale in cooling towers and boilers, but also help corrosion control by dispersing iron oxide.
Basic Boiler System Schematic
Below is a summary of problems associated with the common impurities in water and solutions to each problem.
List Of Problems Caused By Impurities In Water
|
Impurity (Chemical Formula) |
Problems |
Common Chemical Treatment Methods |
|
Alkalinity (HCO3-, CO32- and CaCO3) |
Carryover of feedwater into steam, produce CO2 in steam leading to formation of carbonic acid (acid attack) |
Neutralizing amines, filming amines, combination of both, and lime-soda. |
|
Hardness (calcium and magnesium salts, CaCO3) |
Primary source of scale in heat exchange equipment |
Lime softening, phosphate, chelates and polymers |
|
Iron (Fe3+ and Fe2+) |
Causes boiler and water line deposits |
Phosphate, chelates and polymers |
|
Oxygen (O2) |
Corrosion of water lines, boiler, return lines, heat exchanger equipments, etc. (oxygen attack) |
Oxygen scavengers, filming amines and deaeration |
|
pH |
Corrosion occurs when pH drops below 8.5 |
pH can be lowered by addition of acids and increased by addition of alkalies |
|
Hydrogen Sulfide (H2S) |
Corrosion |
Chlorination |
|
Silica (SiO2) |
Scale in boilers and cooling water systems |
Lime softening |
Care Treat 3 Boiler 2 Arboiler WT, BWT 104P Nor chem, Amertrol AT1240, Drew Ameroid 25 Ltr
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A one-step and one SHOT treatment to control the formation of rust and scale in boilers. Contains alkaline compounds, scale and corrosion inhibitors, oxygen scavengers and sludge conditioners. which resulting in a scale and corrosion control by one shot operation.
Chemical feed should be continuous. Chemical pumping rates can create problems especially for neat feed set ups. Using on/off feed systems such as a recycle timer can create problems. Chemical feed pumps should be sized or product strengths should be adjusted to allow continuous feed.
Steam and carbon dioxide leave continuously, so setting up a neutralizing amine pump to feed intermittently can lead to wide variations in condensate pH control. If sampling is done from a condensate receiver, the tank volume may buffer the variations and the changes may not be noticed, but corrosion could be occurring to areas of the piping that see the rapidly changing pH.
If polymeric dispersants, phosphonates, phosphate, or chelants are fed intermittently into the feedwater using a recycle timer, and the amines are not fed continuously, a cycle of iron slugs returning in the condensate can be followed by slugs of high dispersancy cleaning of the iron from the deaerator and dragging it into the boiler.
Load changes can affect chemical concentrations when the chemical feed is base fed. Example: Steam production of one million lbs./day; 4% blowdown; 20% active boiler polymer product fed at 5 pounds per day. The calculated daily average polymer concentration would be 24 ppm. Assume peak plant production load is 60,000 lbs./hr., but during the overnight hours the load is only 5,000 lbs./hr. If the dispersant is being fed continuously over the 24 hours, during the 8- hour low load period, the boiler polymer concentration would have increased to over 200 ppm. Upon high fire when production resumes, carryover is very possible because of over concentrating the polymeric dispersant.
Chemical feed needs to be paced to steam production, especially where significant load changes occur.
Carbon dioxide can concentrate in steam and condensate making neutralizing amine treatment impractical. Carbon dioxide levels can be relatively low in steam exiting a boiler at only a few ppm, but if there are areas where it becomes “trapped” and can accumulate, concentrations can reach extremely high levels into the hundreds or even thousands of ppm.
CO2 is a non-condensable gas. It has a distribution ratio in the steam piping and condenses at points throughout the system. At the boiling point, the solubility of the gas in water is extremely low. The solubility of the CO2 is actually lower in the condensate than it is in the steam. For the CO2 to escape from the steam into the water it will accumulate in the steam space just above the water level until the partial pressure becomes high enough for the CO2 in the incoming steam to be able to exit into the condensate. This creates a steady state condition of CO2 coming in and exiting, but an area of severe localized corrosion occurs where the carbon dioxide concentration is high.
The highest CO2 concentration normally occurs just above the condensate water level. If there is an area where condensation is occurring and running down pipes or the sides of vessels, the CO2 concentration will be very high and the pH will be about 5.3 – 5.5 in that location creating high corrosion rates.
The solubility of CO2 increases dramatically as the condensate temperature falls below 212 °F. When there is an accumulation of CO2 in an area and the condensate temperature is relatively low, the amount of carbon dioxide going into solution will be extremely high. Where low-pressure steam is used that contains CO2 and the heat exchange process has relatively close temperature differentials between the steam and the condensate, there is potential for high uptake of the CO2 into the condensate and localized low pH.
Neutralizing amines are selected in an effort to condense in the right concentrations to carbon dioxide condensation levels throughout the steam system. Neutralizing amines cannot control corrosion where this localized accumulation of carbon dioxide occurs since the high CO2 overwhelms the demand for the amine. Even point source addition of amine may not be able to satisfy the demand.
Where the concentrating effect of CO2 occurs, methods of reducing the problem include eliminating or minimizing CO2 in the steam, venting off the CO2 in the localized area, eliminating condensate in the area, applying a filming amine or metal passivator, or using higher temperature steam and increasing condensate temperature to reduce the CO2 content in the condensate.