CA1339761C - Corrosion control composition and method for boiler/condensate stem system - Google Patents
Corrosion control composition and method for boiler/condensate stem systemInfo
- Publication number
- CA1339761C CA1339761C CA 597045 CA597045A CA1339761C CA 1339761 C CA1339761 C CA 1339761C CA 597045 CA597045 CA 597045 CA 597045 A CA597045 A CA 597045A CA 1339761 C CA1339761 C CA 1339761C
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- Canada
- Prior art keywords
- molecular weight
- amine
- boiler
- amines
- condensate
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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Classifications
-
- C—CHEMISTRY; METALLURGY
- C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
- C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
- C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
- C23F11/08—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids
- C23F11/10—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in other liquids using organic inhibitors
- C23F11/14—Nitrogen-containing compounds
- C23F11/141—Amines; Quaternary ammonium compounds
-
- C—CHEMISTRY; METALLURGY
- C23—COATING METALLIC MATERIAL; COATING MATERIAL WITH METALLIC MATERIAL; CHEMICAL SURFACE TREATMENT; DIFFUSION TREATMENT OF METALLIC MATERIAL; COATING BY VACUUM EVAPORATION, BY SPUTTERING, BY ION IMPLANTATION OR BY CHEMICAL VAPOUR DEPOSITION, IN GENERAL; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL
- C23F—NON-MECHANICAL REMOVAL OF METALLIC MATERIAL FROM SURFACE; INHIBITING CORROSION OF METALLIC MATERIAL OR INCRUSTATION IN GENERAL; MULTI-STEP PROCESSES FOR SURFACE TREATMENT OF METALLIC MATERIAL INVOLVING AT LEAST ONE PROCESS PROVIDED FOR IN CLASS C23 AND AT LEAST ONE PROCESS COVERED BY SUBCLASS C21D OR C22F OR CLASS C25
- C23F11/00—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent
- C23F11/02—Inhibiting corrosion of metallic material by applying inhibitors to the surface in danger of corrosion or adding them to the corrosive agent in air or gases by adding vapour phase inhibitors
Abstract
A corrosion control composition and method for boiler/condensate steam systems is provided. Corrosion is controlled by the addition to the feedwater of a relatively high molecular weight amine. The high molecular weight amine is formulated so that at the conditions of temperature and pressure in the boiler/condensate steam system, partial degradation into more volatile amines occurs. The resulting blend of neutralizing amines provides the superior corrosion control of a blend of neutralizing amines from a single amine feed. The preferred high molecular weight amine is dimethylaminopropylamine which will partially degrade into dimethylamine, trimethylamine, methylamine, and dimethylaminopropanol.
#37/mm
#37/mm
Description
CORROSION CONTROL COMPOSITION AND METHOD
FOR BOILER/CONDENSATE STEAM SYSTEM
FIELD OF THE INVENTION
The present invention relates to compositions and methods for controlling the metal loss in boiler/condensate steam systems.
BACKGROUND OF THt INVENTION
Iron ana copper corrosion in steam condensate systems results in damage to piping and equipment as well as the loss of nigh quality water and energy. The corrosion proâucts and process chemicals if returned to the boiler can contribute to the formation of damaging boiler deposits thereby reducing the overall system reliability and increasing operating and maintenance costs.
Iron corrodes in water in the absence of oxygen because iron is less noble than hydrogen. In pure water the ferrous hydroxide (Fe(OH)2) formed by iron and water elevates the pH by proviaing hydroxide ions and ferrous ions. This reduces the amount of hydrogen ion which tends to retard corrosion. If the water temperature rises, ferrous hydroxide is converted to magnetite (Fe304) in the absence of oxygen to form a somewhat protective film barrier. At temperatures of over 120~F, mdgnetite is formed based upon the overall reaction: 3 Fe + 4 H20 -- Fe3U4 + 4H2.
Thus, under laboratory conditions the corrosion of iron is self limiting. For actual condensate systems however, the presence of contaminants such as dissolved oxygen and carbon dioxide promote the corrosion reaction. In the presence of oxygen, ferrous hydroxide is unstable and ferric hydroxide is formed. Ferric hydroxide is not a corrosion reaction inhibitor as is ferrous hydroxide. Therefore, the presence of free oxygen in a given system enhances the corrosion reaction.
In addition to iron corrosion in water which is augmented by the presence of oxygen, corrosion of copper by oxygen may also occur. Generally, the resulting formation of cupric oxide is self limiting. If, however, copper complexing agents such as ammonia are present, the copper oxide film cannot become permanently established.
High concentrations of carbon dioxide in the condensate system, at lower pH values (less than 8) have an effect similar to ammonia in dissolving tne copper oxide film.
Carbon dioxide that dissolves in water causes the pH to be depressed and results in the formation of carbonic acid. Carbonic acid promotes the iron corrosion reaction by supplying the reactant H+. The overall reaction is: 2H2CO3 + Fe -- Fe(HCO3)2 + H2. The ferrous bicarbonate is soluble under many conditions and can act as a corrosion reaction retardant. The stability of ferrous bicar-bonate in solution is effected by heat, pH and the partial pressure of carbon dioxide above the condensate. Often, these conditions change from location to location within the boiler/condensate system.
1 33976 i In the boiler, sodium carbonate and sodium bicarbonate react with heat plus water to form sodium hydroxide and carbon dioxide.
Various external makeup water treatment methods can reduce the potential for carbon dioxide corrosion by lowering the alkalinity of the makeup water.
Due to the aqueous solubility of carbon dioxide, ground waters and surface waters contain carbonates among other dissolved solids. When these waters are heated in steam generating systems, the solubility of carbon dioxide decreases and the gas enters the produced steam. Upon condensation, carbon dioxide again dissolves to form carbonates. Since the condensate contains relatively few dissolved solids and thus little buffering capacity, the weakly acidic carbonate species can drastically lower the condensate pH.
In turn, when acidic condensate mixes with makeup water, the steam generator feedwater pH can also decrease.
Carbonate containing waters cause acidic or general corrosion of the iron and copper metallurgies found in condensate and feedwater systems. This type of corrosion is evidenced by a general wastage or by gouging or pitting of the metal surface. If untreated, corrosion can cause failure of condensate return lines, feedwater piping, and other equipment (condensate receivers, pumps, heaters, etc.) associated with steam generator and hot water heating systems.
Several methods have been devised to control acid induced corrosion in these systems. Materials can be added that adsorb to the metal surface to form a thin barrier between the metal and the acidic solution. Examples of effective barrier-forming materials that are routinely used are long chain amines, such as octadecyl-amine, and azoles, such as tolyltriazole.
A second, more often utilized method of controlling carbonate-caused corrosion is the addition of amines to neutralize the carbonate and thereby increase the aqueous pH. Many different amines are utilized, but some commonly used materials include cyclohexylamine, morpholine, and methoxypropylamine. On an equal weight basis, the most effective amines are tnose that possess high basicity and low molecular weight. The high basicity allows attainment of high pH after acid neutralization, and low molecular weight allows greater molar concentrations (and thus more neutralization).
The addition of neutralizing amines neutralizes the acid (H+) generated by the solution of carbon dioxide in condensate.
The amines hydrolyze in water to generate hydroxide ions required for neutralization. By regulating the neutralizing amine feed rate, the condensate pH can be elevated to within a desired range (eg 8.5 to 9.0). Numerous amines can be used for condensate pH neutrali-zation and elevation. The selection of the appropriate amine is currently controlled by the basicity, stability and distri~ution ratio characteristics of the particular amine. The distribution ratio (DR) of an amine is expressed as formula DR equal to amine in vapor phase divided by amine in water phase (condensate) at some defined pressure or temperature.
Amines with a distribution ratio greater than 1.0 have more amine in the vapor phase than the water phase. The distribution ratio is a function of the pressure and the temperature in a boiler/condensate system to be treated. Distribution ratios (at atmospheric pressure) for commonly used neutralizing amines are as follows: Morpholine 0.4; diethylaminoethanol 1.7; dimethylisopro-panol amine 1.7; cyclohexylamine 4.0; ammonia 10Ø The varying distribution ratios of commonly used neutralizing amines affect the loss of the amine from the system as well as the area in the system where the amine is most effective. Amines that have low distribution ratios provide excellent pH control at initial condensation sites, but poor neutralization at the final conden-sation sites. On the other hand, high DR amines are more likely to be found in remote sites in steam that has been in contact with the liquid phase as it passes through tne steam distribution system.
In boiler/condensate systems where the bulk of the steam produced is used for turbine supply, morpholine is most suitable or a blend having a high morpholine content. The low DR for morpholine means that morpholine will be present in the initial condensate formed at the wet end of the turbine. In plants with extensive runs of steam lines, a material with a high DR is more desirable.
In practice, the best protection is typically provided by a blend of amine products containing a variety of materials with differing distribution ratios.
Typical neutralizing amines have DR's from 0.1 to 10, carbon dioxide has a DR of 100 or more depending upon temperature.
Because of this difference in DR's, amines tend to concentrate in the condensate lines closest to the system boiler whereas carbon dioxide tends to concentrate in more remote areas of the condensate return system. Thus, conventional amine addition to the boiler feedwater is not sufficient to protect such remote areas from carbon dioxide induced corrosion, often these lines are unprotected or require satellite feed of amines.
Amines having a relatively high volatility compared to the above treatment amines are known. For example, dimethylamine (DMA), trimethylamine (TMA), and diethylamine (DEA) have properties that make them desirable for use in corrosion inhibition in boiler/condensate systems. For example, DMA which has a DR of from 2 to 5, is an extremely strong base (pKa of 10.77) and due to its molecular weight is capable of neutralizing carbonic acid on an approximately 1:1 molar ratio. TMA is between 2 - 5 times more volatile than cyclohexylamine at boiler pressures from 100 to 1500 psig. DEA has a distribution ratio (at 1000 psig) of 28.
Cyclohexylamine is the most volatile neutralizing inhibitor commonly used in the treatment of steam boiler/condensate systems. Thus, it is believed that DMA, TMA, DEA and other low molecular weight amines would be more effective than cyclohexylamine and other amines used for condensate treatment in following and neutralizing carbon dioxide in the outlying areas of a condensate return system.
However, the extreme volatility, i.e. flammability and high atmospheric vapor pressures, of low molecular weight amines has prevented the production of acceptable product formulations containing volatile, low molecular weight amines such as DEA, DMA
and TMA for use in boiler/condensate system corrosion treatment.
Summary of the Invention The present invention provides a composition and method for controlling corrosion in boiler/condensate aqueous systems. The method of the present invention comprises the addition of a relatively high molecular weight amine to the feedwater of a boiler/condensate water system. The high molecular weight amine partially decomposes, either through hydrolytic cleavage or thermal degradation, to provide more volatile lower molecular weight amines.
The lower molecular weight amines in combination with undecomposed high molecular weight amine provide corrosion control. Such a com~ination provides corrosion control ~y amines witn a ranye of distribution ratios. The high molecular weight amine is selected so that at the typical temperatures and pressures of the Doiler/conden-sate steam system, at least partial decomposition to lower molecularweight amines suc~ as monobasic alkyl amines occurs. Such lower molecular weight amines such as DMA, TMA and DEA are highly volatile and flammable so their addition to the system feedwater in that form presents problems in handling and shipping. Thus, the feed of a single, relatively high molecular weight amine which is relatively easy to handle gives rise in the boiler system to a mixture of several amines which cover a broad range of distribution ratios and thus provides effective coverage of even complex boiler/condensate systems.
The preferred relatively high molecular weight amine of the present invention is dimethylaminopropylamine or N,N-dimethyl-1,3- propanediamine (UMAPA). DMAPA partially ~ecomposes at common boiler conditions to provide monobasic amines such as dimethylamine (DMA) and trimethylamine (TMA). Other relatively high molecular weight amines may also be employed which will partially decompose at common boiler conditions. For example, diethylaminoethanol (DEAE) will partially decompose at common boiler conditions to ethylamino-ethanol (EAE) and diethylamine (DEA). The mechanism of decomposition is not clearly understood but it is believed to be a form of hydrolytic cleavage or thermal degradation.
Description of the Preferred Embodiment The inventors of the present invention attempted to produce accepta~le boiler water/condensate system control agent formulations 133~76t containing a DMA and TMA and other volatile low molecular weight amines. Research into the effectiveness of TMA as a condensation system corrosion control agent indicated that TMA was 2 to 5 times more volatile than cyclohexylamine. Research also indicated that DMA has a DR of from 2 to 5, is an extremely strong base and is capable of neutralizing carbonic acid on approximately 1:1 molar basis. All of these properties indicated a possibility of improved condensate system control through the use of DMA or TMA. Attempts to develop product formulations containing low molecular weight amines which typically have extremely high atmospheric vapor pressures and are highly flammable were unsuccessful. These properties made the use of relatively low molecular weight amines such as DMA and TMA
hazardous and complicated. In addition, DMA and TMA are hazardous to formulate and store limiting their usefulness in commercial settings.
The inventors of the present invention discovered that a relatively high molecular weight amine could be formulated which when exposed to typical temperature and pressure conditions in a boiler system would partially decompose into the desirable, relatively volatile low molecular weight amines. By providing a relatively high molecular weight amine, only a single amine need be formulated, transported, stored and fed to a boiler system. The relatively high molecular weight of the feed amine results in a less volatile amine which is easier to transport, store and to feed.
Proper formulation of the single relatively high molecular weight amine provides for partial decomposition at standard boiler temperature and pressure ranges. The relatively high molecular weight amine is formulated such that upon the partial decomposition relatively low molecular weight amines are formed. Thus, the single feed amine of the present invention provides for the in situ g formation of a mixture of several amines in the boiler/condensate system. These several amines exhibit a broad range of distribution ratios to provide effective corrosion control even in complex boiler/condensate systems.
The preferred relatively high molecular weight amine of the present invention is dimethylaminopropylamine (DMAPA) or N,N-dimethyl-1,3-propanediamine. It has been found that the DMAPA
is relatively easy to formulate, transport, store and feed as a single amine. When DMAPA is subjected to common boiler temperatures and pressures of from 100 to 1500 psig, the DMAPA will partially decompose. The partial decomposition of DMAPA forms DMA and TMA.
The properties of these components, including their DR is given in Table I.
TABLE I
Distribution Ratios Flash MolecularBasicity 100 200 600 Pt.
Amine Weight (pKa) psigpsig psig ~F
DMAPA 102 lO.Ot8.2 1.1 1.9 2.0 84 DMA 45 10.8 2.4 2.1 3.3 60 TMA 59 9.8 15.3 12.6 28.0 20 .
The following lab scale experiment varified the formation of DMA and TMA.
A research scale, electrically heated test ooiler was charged with nitrogen sparged (a mechanical deaeration), deminera-lized water. The water was supplied by high pressure pump to aD-configuration stainless steel boiler having an internal volume of approximately 5 liters. Two 4000 watt Incoloy 800 resistance heaters produced a steam rate of approximately 17 lbs/hr at a steam pressure of 1,450 psig (correspond to a temperature of 593 ~F).
Cycles of concentration were held at approximately 15 by controlling boiler blowdown rate to 1.1 lbs/hr. The saturated steam produced was routed back into the feed tank and mixed with the original feedwater. This follows common industry practice where for economy the maximum amount of condensate is returned to the boiler as feedwater. The feedwater initially contained 200 ppm of DMAPA
(Aldrich 99%) and 1.4 ppm hydrazine for deaeration. The feedwater (to which the condensed steam was recycled) was analyzed by gas chromatography and DMA and TMA were quantitated by comparison to external standards. Table II summarizes the results.
TABLE II
Elapsed Feedwater Composition(ppm) Conductivity Sample Time (hrs.) DMA TMA pH (uS) 12 22 5 9 10.35 160 13 46 11 16 10.40 195 14 79 20 25 10.65 200 94 25 32 10.35 230 1 33976 t As shown, the addition of the single amine, DMAPA
resulted in a steadily increasing concentration of DMA and TMA with time. The elevation in pH is believed to be due to the formation of highly basic DMA while the increase in conductivity is believed to be due to the increasing concentrations of DMA and TMA in the steam, both of which are significantly more volatile than DMAPA. Testing at varying boiler pressures has indicated a relationship between boiler pressure and the rate at which DMAPA decomposes into DMA and TMA.
Additional testing with the relatively high molecular weight amine DMAPA has indicated that in addition to DMA and TMA, other relatively low molecular weight amines also form. The for-mation of methylamine (MA) and dimethylaminopropanol (DMAP) has been confirmed. The formation of other, relatively low molecular weight amines may also occur in the practice of the present invention.
Additional testing with the relatively high molecular weight amine diethylaminoethanol (DEAE) confirmed it's partial decomposition into the volatile, relatively low molecular weight amines ethylaminoethanol (EAE) and diethylamine (DEA). This partial decomposition of DEAE occured at conditions of temperature and pressure common to a typical boiler/condensate steam system.
As shown by the above data, the addition of a single select amine can give rise to the presence in a boiler/condensate system of a mixture of amines which provide a range of distribution ratios thereby providing improved system wide corrosion control.
Selection and formulation of a single, high molecular weight amine which will at least partially decompose to lower molecular weight amines which are more volatile allows the ease of a single amine feed to provide the efficiency of multiple amine treatment.
This efficiency is provided without the problems associated with the feeding of volatile, often highly flammable low molecular weight amines.
While certain features of this invention nave been described in detail with respect to various embodiments thereof, it will, of course, be apparent that other modifications can be made within the spirit and scope of the invention, and it is not intended to limit this invention to the exact detail shown above except insofar as they are defined in the following claims.
FOR BOILER/CONDENSATE STEAM SYSTEM
FIELD OF THE INVENTION
The present invention relates to compositions and methods for controlling the metal loss in boiler/condensate steam systems.
BACKGROUND OF THt INVENTION
Iron ana copper corrosion in steam condensate systems results in damage to piping and equipment as well as the loss of nigh quality water and energy. The corrosion proâucts and process chemicals if returned to the boiler can contribute to the formation of damaging boiler deposits thereby reducing the overall system reliability and increasing operating and maintenance costs.
Iron corrodes in water in the absence of oxygen because iron is less noble than hydrogen. In pure water the ferrous hydroxide (Fe(OH)2) formed by iron and water elevates the pH by proviaing hydroxide ions and ferrous ions. This reduces the amount of hydrogen ion which tends to retard corrosion. If the water temperature rises, ferrous hydroxide is converted to magnetite (Fe304) in the absence of oxygen to form a somewhat protective film barrier. At temperatures of over 120~F, mdgnetite is formed based upon the overall reaction: 3 Fe + 4 H20 -- Fe3U4 + 4H2.
Thus, under laboratory conditions the corrosion of iron is self limiting. For actual condensate systems however, the presence of contaminants such as dissolved oxygen and carbon dioxide promote the corrosion reaction. In the presence of oxygen, ferrous hydroxide is unstable and ferric hydroxide is formed. Ferric hydroxide is not a corrosion reaction inhibitor as is ferrous hydroxide. Therefore, the presence of free oxygen in a given system enhances the corrosion reaction.
In addition to iron corrosion in water which is augmented by the presence of oxygen, corrosion of copper by oxygen may also occur. Generally, the resulting formation of cupric oxide is self limiting. If, however, copper complexing agents such as ammonia are present, the copper oxide film cannot become permanently established.
High concentrations of carbon dioxide in the condensate system, at lower pH values (less than 8) have an effect similar to ammonia in dissolving tne copper oxide film.
Carbon dioxide that dissolves in water causes the pH to be depressed and results in the formation of carbonic acid. Carbonic acid promotes the iron corrosion reaction by supplying the reactant H+. The overall reaction is: 2H2CO3 + Fe -- Fe(HCO3)2 + H2. The ferrous bicarbonate is soluble under many conditions and can act as a corrosion reaction retardant. The stability of ferrous bicar-bonate in solution is effected by heat, pH and the partial pressure of carbon dioxide above the condensate. Often, these conditions change from location to location within the boiler/condensate system.
1 33976 i In the boiler, sodium carbonate and sodium bicarbonate react with heat plus water to form sodium hydroxide and carbon dioxide.
Various external makeup water treatment methods can reduce the potential for carbon dioxide corrosion by lowering the alkalinity of the makeup water.
Due to the aqueous solubility of carbon dioxide, ground waters and surface waters contain carbonates among other dissolved solids. When these waters are heated in steam generating systems, the solubility of carbon dioxide decreases and the gas enters the produced steam. Upon condensation, carbon dioxide again dissolves to form carbonates. Since the condensate contains relatively few dissolved solids and thus little buffering capacity, the weakly acidic carbonate species can drastically lower the condensate pH.
In turn, when acidic condensate mixes with makeup water, the steam generator feedwater pH can also decrease.
Carbonate containing waters cause acidic or general corrosion of the iron and copper metallurgies found in condensate and feedwater systems. This type of corrosion is evidenced by a general wastage or by gouging or pitting of the metal surface. If untreated, corrosion can cause failure of condensate return lines, feedwater piping, and other equipment (condensate receivers, pumps, heaters, etc.) associated with steam generator and hot water heating systems.
Several methods have been devised to control acid induced corrosion in these systems. Materials can be added that adsorb to the metal surface to form a thin barrier between the metal and the acidic solution. Examples of effective barrier-forming materials that are routinely used are long chain amines, such as octadecyl-amine, and azoles, such as tolyltriazole.
A second, more often utilized method of controlling carbonate-caused corrosion is the addition of amines to neutralize the carbonate and thereby increase the aqueous pH. Many different amines are utilized, but some commonly used materials include cyclohexylamine, morpholine, and methoxypropylamine. On an equal weight basis, the most effective amines are tnose that possess high basicity and low molecular weight. The high basicity allows attainment of high pH after acid neutralization, and low molecular weight allows greater molar concentrations (and thus more neutralization).
The addition of neutralizing amines neutralizes the acid (H+) generated by the solution of carbon dioxide in condensate.
The amines hydrolyze in water to generate hydroxide ions required for neutralization. By regulating the neutralizing amine feed rate, the condensate pH can be elevated to within a desired range (eg 8.5 to 9.0). Numerous amines can be used for condensate pH neutrali-zation and elevation. The selection of the appropriate amine is currently controlled by the basicity, stability and distri~ution ratio characteristics of the particular amine. The distribution ratio (DR) of an amine is expressed as formula DR equal to amine in vapor phase divided by amine in water phase (condensate) at some defined pressure or temperature.
Amines with a distribution ratio greater than 1.0 have more amine in the vapor phase than the water phase. The distribution ratio is a function of the pressure and the temperature in a boiler/condensate system to be treated. Distribution ratios (at atmospheric pressure) for commonly used neutralizing amines are as follows: Morpholine 0.4; diethylaminoethanol 1.7; dimethylisopro-panol amine 1.7; cyclohexylamine 4.0; ammonia 10Ø The varying distribution ratios of commonly used neutralizing amines affect the loss of the amine from the system as well as the area in the system where the amine is most effective. Amines that have low distribution ratios provide excellent pH control at initial condensation sites, but poor neutralization at the final conden-sation sites. On the other hand, high DR amines are more likely to be found in remote sites in steam that has been in contact with the liquid phase as it passes through tne steam distribution system.
In boiler/condensate systems where the bulk of the steam produced is used for turbine supply, morpholine is most suitable or a blend having a high morpholine content. The low DR for morpholine means that morpholine will be present in the initial condensate formed at the wet end of the turbine. In plants with extensive runs of steam lines, a material with a high DR is more desirable.
In practice, the best protection is typically provided by a blend of amine products containing a variety of materials with differing distribution ratios.
Typical neutralizing amines have DR's from 0.1 to 10, carbon dioxide has a DR of 100 or more depending upon temperature.
Because of this difference in DR's, amines tend to concentrate in the condensate lines closest to the system boiler whereas carbon dioxide tends to concentrate in more remote areas of the condensate return system. Thus, conventional amine addition to the boiler feedwater is not sufficient to protect such remote areas from carbon dioxide induced corrosion, often these lines are unprotected or require satellite feed of amines.
Amines having a relatively high volatility compared to the above treatment amines are known. For example, dimethylamine (DMA), trimethylamine (TMA), and diethylamine (DEA) have properties that make them desirable for use in corrosion inhibition in boiler/condensate systems. For example, DMA which has a DR of from 2 to 5, is an extremely strong base (pKa of 10.77) and due to its molecular weight is capable of neutralizing carbonic acid on an approximately 1:1 molar ratio. TMA is between 2 - 5 times more volatile than cyclohexylamine at boiler pressures from 100 to 1500 psig. DEA has a distribution ratio (at 1000 psig) of 28.
Cyclohexylamine is the most volatile neutralizing inhibitor commonly used in the treatment of steam boiler/condensate systems. Thus, it is believed that DMA, TMA, DEA and other low molecular weight amines would be more effective than cyclohexylamine and other amines used for condensate treatment in following and neutralizing carbon dioxide in the outlying areas of a condensate return system.
However, the extreme volatility, i.e. flammability and high atmospheric vapor pressures, of low molecular weight amines has prevented the production of acceptable product formulations containing volatile, low molecular weight amines such as DEA, DMA
and TMA for use in boiler/condensate system corrosion treatment.
Summary of the Invention The present invention provides a composition and method for controlling corrosion in boiler/condensate aqueous systems. The method of the present invention comprises the addition of a relatively high molecular weight amine to the feedwater of a boiler/condensate water system. The high molecular weight amine partially decomposes, either through hydrolytic cleavage or thermal degradation, to provide more volatile lower molecular weight amines.
The lower molecular weight amines in combination with undecomposed high molecular weight amine provide corrosion control. Such a com~ination provides corrosion control ~y amines witn a ranye of distribution ratios. The high molecular weight amine is selected so that at the typical temperatures and pressures of the Doiler/conden-sate steam system, at least partial decomposition to lower molecularweight amines suc~ as monobasic alkyl amines occurs. Such lower molecular weight amines such as DMA, TMA and DEA are highly volatile and flammable so their addition to the system feedwater in that form presents problems in handling and shipping. Thus, the feed of a single, relatively high molecular weight amine which is relatively easy to handle gives rise in the boiler system to a mixture of several amines which cover a broad range of distribution ratios and thus provides effective coverage of even complex boiler/condensate systems.
The preferred relatively high molecular weight amine of the present invention is dimethylaminopropylamine or N,N-dimethyl-1,3- propanediamine (UMAPA). DMAPA partially ~ecomposes at common boiler conditions to provide monobasic amines such as dimethylamine (DMA) and trimethylamine (TMA). Other relatively high molecular weight amines may also be employed which will partially decompose at common boiler conditions. For example, diethylaminoethanol (DEAE) will partially decompose at common boiler conditions to ethylamino-ethanol (EAE) and diethylamine (DEA). The mechanism of decomposition is not clearly understood but it is believed to be a form of hydrolytic cleavage or thermal degradation.
Description of the Preferred Embodiment The inventors of the present invention attempted to produce accepta~le boiler water/condensate system control agent formulations 133~76t containing a DMA and TMA and other volatile low molecular weight amines. Research into the effectiveness of TMA as a condensation system corrosion control agent indicated that TMA was 2 to 5 times more volatile than cyclohexylamine. Research also indicated that DMA has a DR of from 2 to 5, is an extremely strong base and is capable of neutralizing carbonic acid on approximately 1:1 molar basis. All of these properties indicated a possibility of improved condensate system control through the use of DMA or TMA. Attempts to develop product formulations containing low molecular weight amines which typically have extremely high atmospheric vapor pressures and are highly flammable were unsuccessful. These properties made the use of relatively low molecular weight amines such as DMA and TMA
hazardous and complicated. In addition, DMA and TMA are hazardous to formulate and store limiting their usefulness in commercial settings.
The inventors of the present invention discovered that a relatively high molecular weight amine could be formulated which when exposed to typical temperature and pressure conditions in a boiler system would partially decompose into the desirable, relatively volatile low molecular weight amines. By providing a relatively high molecular weight amine, only a single amine need be formulated, transported, stored and fed to a boiler system. The relatively high molecular weight of the feed amine results in a less volatile amine which is easier to transport, store and to feed.
Proper formulation of the single relatively high molecular weight amine provides for partial decomposition at standard boiler temperature and pressure ranges. The relatively high molecular weight amine is formulated such that upon the partial decomposition relatively low molecular weight amines are formed. Thus, the single feed amine of the present invention provides for the in situ g formation of a mixture of several amines in the boiler/condensate system. These several amines exhibit a broad range of distribution ratios to provide effective corrosion control even in complex boiler/condensate systems.
The preferred relatively high molecular weight amine of the present invention is dimethylaminopropylamine (DMAPA) or N,N-dimethyl-1,3-propanediamine. It has been found that the DMAPA
is relatively easy to formulate, transport, store and feed as a single amine. When DMAPA is subjected to common boiler temperatures and pressures of from 100 to 1500 psig, the DMAPA will partially decompose. The partial decomposition of DMAPA forms DMA and TMA.
The properties of these components, including their DR is given in Table I.
TABLE I
Distribution Ratios Flash MolecularBasicity 100 200 600 Pt.
Amine Weight (pKa) psigpsig psig ~F
DMAPA 102 lO.Ot8.2 1.1 1.9 2.0 84 DMA 45 10.8 2.4 2.1 3.3 60 TMA 59 9.8 15.3 12.6 28.0 20 .
The following lab scale experiment varified the formation of DMA and TMA.
A research scale, electrically heated test ooiler was charged with nitrogen sparged (a mechanical deaeration), deminera-lized water. The water was supplied by high pressure pump to aD-configuration stainless steel boiler having an internal volume of approximately 5 liters. Two 4000 watt Incoloy 800 resistance heaters produced a steam rate of approximately 17 lbs/hr at a steam pressure of 1,450 psig (correspond to a temperature of 593 ~F).
Cycles of concentration were held at approximately 15 by controlling boiler blowdown rate to 1.1 lbs/hr. The saturated steam produced was routed back into the feed tank and mixed with the original feedwater. This follows common industry practice where for economy the maximum amount of condensate is returned to the boiler as feedwater. The feedwater initially contained 200 ppm of DMAPA
(Aldrich 99%) and 1.4 ppm hydrazine for deaeration. The feedwater (to which the condensed steam was recycled) was analyzed by gas chromatography and DMA and TMA were quantitated by comparison to external standards. Table II summarizes the results.
TABLE II
Elapsed Feedwater Composition(ppm) Conductivity Sample Time (hrs.) DMA TMA pH (uS) 12 22 5 9 10.35 160 13 46 11 16 10.40 195 14 79 20 25 10.65 200 94 25 32 10.35 230 1 33976 t As shown, the addition of the single amine, DMAPA
resulted in a steadily increasing concentration of DMA and TMA with time. The elevation in pH is believed to be due to the formation of highly basic DMA while the increase in conductivity is believed to be due to the increasing concentrations of DMA and TMA in the steam, both of which are significantly more volatile than DMAPA. Testing at varying boiler pressures has indicated a relationship between boiler pressure and the rate at which DMAPA decomposes into DMA and TMA.
Additional testing with the relatively high molecular weight amine DMAPA has indicated that in addition to DMA and TMA, other relatively low molecular weight amines also form. The for-mation of methylamine (MA) and dimethylaminopropanol (DMAP) has been confirmed. The formation of other, relatively low molecular weight amines may also occur in the practice of the present invention.
Additional testing with the relatively high molecular weight amine diethylaminoethanol (DEAE) confirmed it's partial decomposition into the volatile, relatively low molecular weight amines ethylaminoethanol (EAE) and diethylamine (DEA). This partial decomposition of DEAE occured at conditions of temperature and pressure common to a typical boiler/condensate steam system.
As shown by the above data, the addition of a single select amine can give rise to the presence in a boiler/condensate system of a mixture of amines which provide a range of distribution ratios thereby providing improved system wide corrosion control.
Selection and formulation of a single, high molecular weight amine which will at least partially decompose to lower molecular weight amines which are more volatile allows the ease of a single amine feed to provide the efficiency of multiple amine treatment.
This efficiency is provided without the problems associated with the feeding of volatile, often highly flammable low molecular weight amines.
While certain features of this invention nave been described in detail with respect to various embodiments thereof, it will, of course, be apparent that other modifications can be made within the spirit and scope of the invention, and it is not intended to limit this invention to the exact detail shown above except insofar as they are defined in the following claims.
Claims (4)
1. A method of controlling corrosion in boiler/condensate aqueous systems comprising adding to the system an effective amount of at least one volatile, flammable, relatively low molecular weight amine by feeding to the system at least one, less volatile, relatively high molecular weight amine which when subjected to conditions of temperature and pressure in the system partially decomposes into said at least one relatively low molecular weight amine, wherein said high molecular weight amine is dimethylaminopropylamine; and wherein said low molecular weight amine is dimethylamine, trimethylamine or diethylamine.
2. A method of controlling corrosion in a boiler/condensate aqueous system comprising treating the system with an effective amount of a mixture of amines of varying relative molecular weights and volatilaties by feeding to said system an amine having relatively high molecular weight and relatively low volatility which when exposed to conditions of temperature and pressure in the system at least partially decomposes into lower molecular weight, higher volatility amines, wherein said high molecular weight amine is dimehtylaminopropylamine; and wherein said lower molecular weight amines are dimethylamine, trimethylamine, and diethylamine.
3. A corrosion control additive for boiler/condensate aqueous systems comprising an effective amount of a mixture of amines of varying relative molecular weights, volatilaties and flammabilities, said mixture including at least one relatively high molecular weight amine and the relatively low molecular weight decomposition products thereof, wherein said relatively high molecular weight amine is dimethylaminopropylamine; and wherein said relatively low molecular weight decomposition products are dimethylamine, trimethylamine and diethylamine.
4. The corrosion control additive of claim 3, wherein said mixture is formed by the in situ partial decomposition of said relatively high molecular weight amine.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US21748988A | 1988-07-11 | 1988-07-11 | |
| US07/217,489 | 1988-07-11 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1339761C true CA1339761C (en) | 1998-03-24 |
Family
ID=22811307
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA 597045 Expired - Fee Related CA1339761C (en) | 1988-07-11 | 1989-04-18 | Corrosion control composition and method for boiler/condensate stem system |
Country Status (4)
| Country | Link |
|---|---|
| EP (1) | EP0351099A1 (en) |
| AU (1) | AU612491B2 (en) |
| CA (1) | CA1339761C (en) |
| NZ (1) | NZ228797A (en) |
Families Citing this family (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| JP2809532B2 (en) * | 1991-10-01 | 1998-10-08 | 伯東 株式会社 | Metal corrosion inhibitor |
| CA2091097A1 (en) * | 1992-04-08 | 1993-10-09 | Betzdearborn Inc. | Boiler double buffers |
| EP0807696B1 (en) * | 1996-05-06 | 1999-07-28 | Faborga S.A. | Process for condirioning the feed water of once-through forced flow steam generators. |
| DE19827759A1 (en) * | 1998-06-23 | 1999-12-30 | Reicon Waermetechnik Und Wasse | Process for protecting metallic components from corrosion in drying plants in the construction industry |
Family Cites Families (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3029125A (en) * | 1956-05-10 | 1962-04-10 | Nalco Chemical Co | Inhibition of corrosion in return steam condensate lines |
| ATE27832T1 (en) * | 1983-08-03 | 1987-07-15 | Ouest Union Chim Ind | CORROSION INHIBITING COMPOSITION FOR PROTECTING METAL SURFACES OF A PLANT USING WATER AS THERMAL OR ENERGETIC FLUID, AND METHOD OF PROTECTING SUCH SURFACE. |
| US4862042A (en) * | 1985-04-26 | 1989-08-29 | Herrick Kennan C | Apparatus and method for forming segmented luminosity in gas discharge tubes |
| US4726914A (en) * | 1986-10-10 | 1988-02-23 | International Minerals & Chemical Corp. | Corrosion inhibitors |
-
1989
- 1989-04-18 CA CA 597045 patent/CA1339761C/en not_active Expired - Fee Related
- 1989-04-19 NZ NZ22879789A patent/NZ228797A/en unknown
- 1989-06-08 AU AU36209/89A patent/AU612491B2/en not_active Expired
- 1989-06-29 EP EP89306603A patent/EP0351099A1/en not_active Withdrawn
Also Published As
| Publication number | Publication date |
|---|---|
| AU3620989A (en) | 1990-01-11 |
| EP0351099A1 (en) | 1990-01-17 |
| NZ228797A (en) | 1990-11-27 |
| AU612491B2 (en) | 1991-07-11 |
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