CA2805404C - Use of alpha-amino ethers for the removal of hydrogen sulfide from hydrocarbons - Google Patents
Use of alpha-amino ethers for the removal of hydrogen sulfide from hydrocarbons Download PDFInfo
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- CA2805404C CA2805404C CA2805404A CA2805404A CA2805404C CA 2805404 C CA2805404 C CA 2805404C CA 2805404 A CA2805404 A CA 2805404A CA 2805404 A CA2805404 A CA 2805404A CA 2805404 C CA2805404 C CA 2805404C
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- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
- C10G29/20—Organic compounds not containing metal atoms
-
- C—CHEMISTRY; METALLURGY
- C07—ORGANIC CHEMISTRY
- C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
- C07C7/00—Purification; Separation; Use of additives
- C07C7/148—Purification; Separation; Use of additives by treatment giving rise to a chemical modification of at least one compound
- C07C7/152—Purification; Separation; Use of additives by treatment giving rise to a chemical modification of at least one compound by forming adducts or complexes
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G29/00—Refining of hydrocarbon oils, in the absence of hydrogen, with other chemicals
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/202—Heteroatoms content, i.e. S, N, O, P
-
- C—CHEMISTRY; METALLURGY
- C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
- C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
- C10G2300/00—Aspects relating to hydrocarbon processing covered by groups C10G1/00 - C10G99/00
- C10G2300/20—Characteristics of the feedstock or the products
- C10G2300/201—Impurities
- C10G2300/207—Acid gases, e.g. H2S, COS, SO2, HCN
Abstract
The invention provides a method of removing hydrogen sulfide from hydrocarbon fluids. The method involves using an alpha-amino ether as a hydrogen sulfide scavenger. This allows for the introduction of an oil soluble scavenger in lieu of water-soluble scavengers.
Description
USE OF ALPHA-AMINO ETHERS FOR THE REMOVAL OF HYDROGEN SULFIDE
FROM HYDROCARBONS
Cross-Reference to Related Applications None.
Statement Regarding Federally Sponsored Research or Development Not Applicable.
Background of the Invention This invention relates generally to the treatment of sour gas and liquid hydrocarbon to remove or reduce the levels of hydrogen sulfide therein. The toxicity of hydrogen im sulfide in hydrocarbon fluids is well known in the industry. This has caused considerable expense and efforts to be expended annually to reduce its content to a safe level.
In large production facilities, it is generally more economical to install a regenerative system for treating sour gas streams. These systems typically employ a compound used in an absorption tower to contact the produced fluids and selectively absorb the hydrogen sulfide and possibly other toxic materials such as carbon dioxide and mercaptans. The absorption compound is then regenerated and reused in the system. Typical hydrogen sulfide absorption materials include alkanolamines, PEG, hindered amines, and other species that can be regenerated.
Nonregenerative scavengers for small plant hydrogen sulfide removal fall into four general categories: 1) aldehyde based, 2) metallic oxide based, 3) caustic based, and 4) other processes. In the removal of hydrogen sulfide by nonregenerative compounds, the scavenger reacts with the hydrogen sulfide to form a nonlethal compound or a compound, which can be removed from the hydrocarbon. For example, when formaldehyde reacts with hydrogen sulfide a chemical compound known as forinthionals (e.g., trithiane) is formed.
Prior Art aldehyde scavengers typically include low molecular weight aldehydes and ketones and adducts thereof. The low molecular weight aldehydes may also be combined with an alkyl or alkanolarnine as disclosed in US Patent 4,748,011. Other aldehyde derived scavengers include the reaction product of low molecular weight alkanolamines and aldehydes as disclosed in US Patent 4,978,512. PCT Application WO 92/01481 discloses a method of reducing sulfides in different applications using certain tri-substituted-hexahydro-s-triazines.
German reference DE4027300 discloses a regenerative solvent for removing H2S
and mercaptans. US Patent 5,347,004 discloses the use of 1,3,5 alkoxyalkylene hexahydro triazines.
PCT Application WO 91 US 5232 discloses hydroxyalkyl triazine scavengers, specifically an To N,1\r,N"-tris(2-hydroxyethyl)hexahydro-s-triazine. US Patent 5,774,024 discloses the combination of an alkyl triazine scavenger and quaternary ammonium salt, where the quaternary ammonium salt enhances the effectiveness of the alkyl-triazine.. These prior art attempts however are frequently water-based chemicals and require significant mixing to allow the scavenger to effectively contact the hydrocarbon fluid and remove the hydrogen sulfide.
Thus there is clear need and utility for an improved method of scavenging hydrogen sulfide from hydrocarbon fluids using scavengers that are soluble in the fluid that is being treated. The art described in this section is not intended to constitute an admission that any patent, publication or other information referred to herein is "prior art"
with respect to this invention, unless specifically designated as such. In addition, this section should not be construed to mean that a search has been made or that no other pertinent information as defined in 37 CFR
1.56(a) exists.
Brief Summary of the Invention At least one embodiment of the invention is directed towards a method for
FROM HYDROCARBONS
Cross-Reference to Related Applications None.
Statement Regarding Federally Sponsored Research or Development Not Applicable.
Background of the Invention This invention relates generally to the treatment of sour gas and liquid hydrocarbon to remove or reduce the levels of hydrogen sulfide therein. The toxicity of hydrogen im sulfide in hydrocarbon fluids is well known in the industry. This has caused considerable expense and efforts to be expended annually to reduce its content to a safe level.
In large production facilities, it is generally more economical to install a regenerative system for treating sour gas streams. These systems typically employ a compound used in an absorption tower to contact the produced fluids and selectively absorb the hydrogen sulfide and possibly other toxic materials such as carbon dioxide and mercaptans. The absorption compound is then regenerated and reused in the system. Typical hydrogen sulfide absorption materials include alkanolamines, PEG, hindered amines, and other species that can be regenerated.
Nonregenerative scavengers for small plant hydrogen sulfide removal fall into four general categories: 1) aldehyde based, 2) metallic oxide based, 3) caustic based, and 4) other processes. In the removal of hydrogen sulfide by nonregenerative compounds, the scavenger reacts with the hydrogen sulfide to form a nonlethal compound or a compound, which can be removed from the hydrocarbon. For example, when formaldehyde reacts with hydrogen sulfide a chemical compound known as forinthionals (e.g., trithiane) is formed.
Prior Art aldehyde scavengers typically include low molecular weight aldehydes and ketones and adducts thereof. The low molecular weight aldehydes may also be combined with an alkyl or alkanolarnine as disclosed in US Patent 4,748,011. Other aldehyde derived scavengers include the reaction product of low molecular weight alkanolamines and aldehydes as disclosed in US Patent 4,978,512. PCT Application WO 92/01481 discloses a method of reducing sulfides in different applications using certain tri-substituted-hexahydro-s-triazines.
German reference DE4027300 discloses a regenerative solvent for removing H2S
and mercaptans. US Patent 5,347,004 discloses the use of 1,3,5 alkoxyalkylene hexahydro triazines.
PCT Application WO 91 US 5232 discloses hydroxyalkyl triazine scavengers, specifically an To N,1\r,N"-tris(2-hydroxyethyl)hexahydro-s-triazine. US Patent 5,774,024 discloses the combination of an alkyl triazine scavenger and quaternary ammonium salt, where the quaternary ammonium salt enhances the effectiveness of the alkyl-triazine.. These prior art attempts however are frequently water-based chemicals and require significant mixing to allow the scavenger to effectively contact the hydrocarbon fluid and remove the hydrogen sulfide.
Thus there is clear need and utility for an improved method of scavenging hydrogen sulfide from hydrocarbon fluids using scavengers that are soluble in the fluid that is being treated. The art described in this section is not intended to constitute an admission that any patent, publication or other information referred to herein is "prior art"
with respect to this invention, unless specifically designated as such. In addition, this section should not be construed to mean that a search has been made or that no other pertinent information as defined in 37 CFR
1.56(a) exists.
Brief Summary of the Invention At least one embodiment of the invention is directed towards a method for
2 removing hydrogen sulfide from a hydrocarbon fluid. The method comprises contacting the fluid with an effective amount of a composition comprising a hydrogen sulfide scavenger. The amount of hydrogen sulfide scavenger is sufficient to react with the hydrogen sulfide to reduce the amount hydrogen sulfide released into the vapor space. The reaction product of the hydrogen sulfide scavenger and the hydrogen sulfide remain soluble in the hydrocarbon fluid. The hydrogen sulfide scavenger contains at least one alpha-amino ether.
The composition may include one item selected from the list consisting of:
N,N'-oxybis(rnethylene)bis(N,N-dibutylamine), N,N'-(methylenebis(oxy)bis(methylene))bis(N,N-dibutylamine), and any combination thereof.
The reaction product of the sulfide scavenging formulation and the hydrogen sulfide may not form a separate fluid layer. The method may also further comprise the step of reacting a secondary amine with a formaldehyde equivalent to form at least some of the scavenging formulation. The hydrocarbon fluid may be a liquid.
Detailed Description of the Invention For purposes of this application the definition of these terms is as follows:
"Alpha-amino ether" means a molecule according to the formula:
R2 "4 Where: RI, R2, R3,R1,are carbon containing side chains containing 1 ¨20 carbon atoms and includes cyclic and acyclic compounds. The cyclic compounds can be aromatic or non-aromatic.
The composition may include one item selected from the list consisting of:
N,N'-oxybis(rnethylene)bis(N,N-dibutylamine), N,N'-(methylenebis(oxy)bis(methylene))bis(N,N-dibutylamine), and any combination thereof.
The reaction product of the sulfide scavenging formulation and the hydrogen sulfide may not form a separate fluid layer. The method may also further comprise the step of reacting a secondary amine with a formaldehyde equivalent to form at least some of the scavenging formulation. The hydrocarbon fluid may be a liquid.
Detailed Description of the Invention For purposes of this application the definition of these terms is as follows:
"Alpha-amino ether" means a molecule according to the formula:
R2 "4 Where: RI, R2, R3,R1,are carbon containing side chains containing 1 ¨20 carbon atoms and includes cyclic and acyclic compounds. The cyclic compounds can be aromatic or non-aromatic.
3 Examples include but are not limited to, methyl, ethyl, propyl, tert-butyl, cyclopentyl, cyclohexyl, morpholino, and phenyl, and they all can be the same group or one or more different groups. B is an ether group, which is either an oxygen atom or a group having an oxygen atom at both ends (such as -OCH20- or-OCsUt0-).
"Formaldehyde equivalent" means a composition of matter containing at least one group according to the formula: (CH20),1 in which n is an integer greater than or equal to 1, and/or a composition of matter including formaldehyde or related molecules such as paraformaldehyde, and/or s-trioxane.
"Hydrocarbon fluid" means a liquid or gas predominantly comprising organic material including but not limited to kerosene, crude oil, crude oil emulsions, oilfield condensate, petroleum residua, refined fuels, distillate fuels, fuel oil, heating oils, diesel fuel, gasoline, jet fuel, bunker fuel oils, and any combination thereof.
"Non-Regenerative Scavenger'' means a scavenger, which is consumed by the process of scavenging.
"Regenerative Scavenger" means a scavenger, which is not consumed by the process of scavenging.
"Scavenger" means a composition of matter, such as but not limited to alpha-amino ethers, useful in reducing the amount of or mitigating the effects of some other composition of matter, such as but not limited to hydrogen sulfide, in a fluid medium.
In the event that the above definitions or a description stated elsewhere in this application is inconsistent with a meaning (explicit or implicit) which is commonly used, in a dictionary, or stated in a source referenced herein, the application and the claim terms in particular are understood to be construed according to the definition or description in this application, and not according to the common definition, or dictionary definition.
"Formaldehyde equivalent" means a composition of matter containing at least one group according to the formula: (CH20),1 in which n is an integer greater than or equal to 1, and/or a composition of matter including formaldehyde or related molecules such as paraformaldehyde, and/or s-trioxane.
"Hydrocarbon fluid" means a liquid or gas predominantly comprising organic material including but not limited to kerosene, crude oil, crude oil emulsions, oilfield condensate, petroleum residua, refined fuels, distillate fuels, fuel oil, heating oils, diesel fuel, gasoline, jet fuel, bunker fuel oils, and any combination thereof.
"Non-Regenerative Scavenger'' means a scavenger, which is consumed by the process of scavenging.
"Regenerative Scavenger" means a scavenger, which is not consumed by the process of scavenging.
"Scavenger" means a composition of matter, such as but not limited to alpha-amino ethers, useful in reducing the amount of or mitigating the effects of some other composition of matter, such as but not limited to hydrogen sulfide, in a fluid medium.
In the event that the above definitions or a description stated elsewhere in this application is inconsistent with a meaning (explicit or implicit) which is commonly used, in a dictionary, or stated in a source referenced herein, the application and the claim terms in particular are understood to be construed according to the definition or description in this application, and not according to the common definition, or dictionary definition.
4 In light of the above, in the event that a term can only be understood if it is construed by a dictionary, if the term is defined by the Kirk-Othmer Encyclopedia of Chemical Technology, 5th Edition, (2005), (Published by Wiley, John & Sons, Inc.) this definition shall control how the term is to be defined in the claims.
In at least one embodiment, the hydrogen sulfide in a hydrocarbon fluid is reduced by the introduction of an alpha-amino ether scavenger into the fluid.
In at least one embodiment the alpha-amino ether is a portion of a scavenging formulation is used in a hydrocarbon fluid. The formulation comprises alpha-amino ether and can consist of a carrier liquid as well. The formulation can be introduced into the hydrocarbon fluid by mechanical means including but not limited to injection pumps or any mechanism disclosed in US Patents 5,744,024 and 5,840,177. In the context of gaseous hydrocarbon fluids, the gas may be passed through an absorption tower containing a scavenging formulation.
One advantage of the use of the alpha-amino ether scavenger over other scavengers is that the alpha-amino ether scavenger is soluble in hydrocarbon fluids, since it is not a water-based product.
As illustrated in FIG. 1, in at least one embodiment the hydrogen sulfide scavenger is produced by reacting a secondary amine with formaldehyde or other formaldehyde equivalents such as paraformaldehyde or s-trioxane. This produces a composition of matter that predominantly comprises two forms of alpha-amino ethers (compounds B and C). 10%-25% of the composition is a mono oxygen ether (compound B) and 50%-80% of the composition is a bis oxygen ether with a single carbon atom between the ether oxygens (compound C). The reaction product also comprises 10-25% of the non-ether diamine (compound A). Compound A is an unavoidable side product of the reaction mixture. The reaction can be performed by mixing the reactants in solvents such as but not limited to Naphtha (Petroleum) Heavy Aromatic Solvents (such as Aromatic 150 and Solvesso by ExxonMobil) or Naphtha Light Aromatic Solvents (such as (Aromatic 100 by Americhem Sales Corporation).
In at least one embodiment the ratio of amine to formaldehyde in the reaction mixture is inclusively within the range of L5:1 to 1:1.5 and is preferably between 1.2:1 and 1:1.2.
In at least one embodiment any of the R and R' groups correspond to any of the RI, R2, R3, and R4, groups described in the definition of "alpha-amino ether".
In at least one embodiment when R is n-butyl and R' is H then:
Compound A is N,N,N',N'-tetrabutylmethanediamine, Compound B is N,N'-oxybis(methylene)bis(N,N-dibutylene), and Compound C is N,N'-(methylenebis(oxy)bis(methylene))bis(N,N'-dibutylamine).
At least some contemplated scavenging compositions include formulations comprising:
(Compound A, B, and C), (A and B), (A and C), (B and C), (C alone), and (B
alone).
EXAMPLES
The foregoing may be better understood by reference to the following example, which is presented for purposes of illustration and is not intended to limit the scope of the invention.
Samples of hydrocarbon fluids were tested to determine the efficiency of the scavenger. Table 1 compares the inventive composition in naphtha at 22 degrees C, Table 2 kerosene at 22 degrees C, and Table 3 slurry oil (such as carbon black oil, decant oil, and clarified slurry oil produced in a refinery) at 97 degrees C. The samples contained variable levels of hydrogen sulfide and were comparatively treated with various dosages of alpha-amino ether scavenger or left untreated, and the amounts H2S
reduced in each sample was recorded.
Table 1: Naphtha 22 it inks ppm 1125 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 800 Compounds A- C 20 780 97.5 0.2 2 h Compounds A- C 6 794 99.2 03 2 h Compounds A- C 3 797 99.6 0_2 24 h Compounds A.- C <1 >799 99.9 03 24h 2h Compounds A- C 12 (4) 788 (796) 98.5 (99_5) 0.2 (24h) Table &wing 22 C
kyjg ppm H25 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 1400 Compounds A -C 400 1000 71 0,1 2 h Compounds A -C 220 1180 84 02 2 h Compounds A - C 95 1305 93 0.3 2 h Table 3: Slurry oil 97 litylo ppm 1125 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 1300 Compounds A - C 450 850 65 0_1 2.5 h Compounds A - C 240 1060 82 0,2 2.5 h Compounds A - C 180 1120 86 0.3 2.5 h Compounds A - C 140 1160 89 0.4 2.5 h Compounds A - C 90 1210 93 0.5 2_5 h The amount of H2S present in the vapor space was determined by measuring the vapor space hydrogen sulfide levels according to ASTM D5705-03.
The test procedure was modified by running at temperatures other than 60 C. A one-gallon sample was divided into multiple 500 milliliter samples for testing. The treated containers were pre-dosed with Compounds A-C and then the fluid being tested was poured into the container.
In each example, the dose ratio was the number used to determine the ppm treat rate for the sample. For table 1 the untreated sample resulted in a vapor space hydrogen sulfide measurement of 800 ppm. A dose ratio of 0.2 indicates the sample was treated with 160 ppm of additive. A dose ratio of 0.3 indicates that the sample was treated with 240 ppm of additive.
This data demonstrates that the presence of the alpha-amino ether scavenger reduced the H2S in the hydrocarbon fluids in a relatively short amount of time and continued to reduce the H2S the longer the sample was exposed to the alpha-amino ether prior to testing.
While this invention may be embodied in many different forms, there are shown in the drawings and described in detail herein specific preferred embodiments of the invention. The present disclosure is an exemplification of the principles of the invention and is not intended to limit the invention to the particular embodiments illustrated. Furthermore, the invention encompasses any possible combination of some or all of the various embodiments described herein and incorporated herein.
The above disclosure is intended to be illustrative and not exhaustive. This description will suggest many variations and alternatives to one of ordinary skill in this art. All these alternatives and variations are intended to be included within the scope of the claims where the term "comprising" means "including, but not limited to". Those familiar with the art may recognize other equivalents to the specific embodiments described herein which equivalents are also intended to be encompassed by the claims.
All ranges and parameters disclosed herein are understood to encompass any and all subranges subsumed therein, and every number between the endpoints. For example, a stated range of "1 to 10" should be considered to include any and all subranges between (and inclusive of) the minimum value of 1 and the maximum value of 10; that is, all subranges beginning with a minimum value of 1 or more, (e.g. 1 to 6.1), and ending with a maximum value of 10 or less, (e.g. 2.3 to 9.4,3 to 8,4 to 7), and finally to each number 1, 2, 3, 4, 5, 6, 7, 8, 9, and 10 contained within the range.
This completes the description of the preferred and alternate embodiments of the invention. Those skilled in the art may recognize other equivalents to the specific embodiment described herein which equivalents are intended to be encompassed by the claims attached hereto.
In at least one embodiment, the hydrogen sulfide in a hydrocarbon fluid is reduced by the introduction of an alpha-amino ether scavenger into the fluid.
In at least one embodiment the alpha-amino ether is a portion of a scavenging formulation is used in a hydrocarbon fluid. The formulation comprises alpha-amino ether and can consist of a carrier liquid as well. The formulation can be introduced into the hydrocarbon fluid by mechanical means including but not limited to injection pumps or any mechanism disclosed in US Patents 5,744,024 and 5,840,177. In the context of gaseous hydrocarbon fluids, the gas may be passed through an absorption tower containing a scavenging formulation.
One advantage of the use of the alpha-amino ether scavenger over other scavengers is that the alpha-amino ether scavenger is soluble in hydrocarbon fluids, since it is not a water-based product.
As illustrated in FIG. 1, in at least one embodiment the hydrogen sulfide scavenger is produced by reacting a secondary amine with formaldehyde or other formaldehyde equivalents such as paraformaldehyde or s-trioxane. This produces a composition of matter that predominantly comprises two forms of alpha-amino ethers (compounds B and C). 10%-25% of the composition is a mono oxygen ether (compound B) and 50%-80% of the composition is a bis oxygen ether with a single carbon atom between the ether oxygens (compound C). The reaction product also comprises 10-25% of the non-ether diamine (compound A). Compound A is an unavoidable side product of the reaction mixture. The reaction can be performed by mixing the reactants in solvents such as but not limited to Naphtha (Petroleum) Heavy Aromatic Solvents (such as Aromatic 150 and Solvesso by ExxonMobil) or Naphtha Light Aromatic Solvents (such as (Aromatic 100 by Americhem Sales Corporation).
In at least one embodiment the ratio of amine to formaldehyde in the reaction mixture is inclusively within the range of L5:1 to 1:1.5 and is preferably between 1.2:1 and 1:1.2.
In at least one embodiment any of the R and R' groups correspond to any of the RI, R2, R3, and R4, groups described in the definition of "alpha-amino ether".
In at least one embodiment when R is n-butyl and R' is H then:
Compound A is N,N,N',N'-tetrabutylmethanediamine, Compound B is N,N'-oxybis(methylene)bis(N,N-dibutylene), and Compound C is N,N'-(methylenebis(oxy)bis(methylene))bis(N,N'-dibutylamine).
At least some contemplated scavenging compositions include formulations comprising:
(Compound A, B, and C), (A and B), (A and C), (B and C), (C alone), and (B
alone).
EXAMPLES
The foregoing may be better understood by reference to the following example, which is presented for purposes of illustration and is not intended to limit the scope of the invention.
Samples of hydrocarbon fluids were tested to determine the efficiency of the scavenger. Table 1 compares the inventive composition in naphtha at 22 degrees C, Table 2 kerosene at 22 degrees C, and Table 3 slurry oil (such as carbon black oil, decant oil, and clarified slurry oil produced in a refinery) at 97 degrees C. The samples contained variable levels of hydrogen sulfide and were comparatively treated with various dosages of alpha-amino ether scavenger or left untreated, and the amounts H2S
reduced in each sample was recorded.
Table 1: Naphtha 22 it inks ppm 1125 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 800 Compounds A- C 20 780 97.5 0.2 2 h Compounds A- C 6 794 99.2 03 2 h Compounds A- C 3 797 99.6 0_2 24 h Compounds A.- C <1 >799 99.9 03 24h 2h Compounds A- C 12 (4) 788 (796) 98.5 (99_5) 0.2 (24h) Table &wing 22 C
kyjg ppm H25 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 1400 Compounds A -C 400 1000 71 0,1 2 h Compounds A -C 220 1180 84 02 2 h Compounds A - C 95 1305 93 0.3 2 h Table 3: Slurry oil 97 litylo ppm 1125 Percent Dose Treatment (ppm) Reduced Reduction Ratio Time Untreated 1300 Compounds A - C 450 850 65 0_1 2.5 h Compounds A - C 240 1060 82 0,2 2.5 h Compounds A - C 180 1120 86 0.3 2.5 h Compounds A - C 140 1160 89 0.4 2.5 h Compounds A - C 90 1210 93 0.5 2_5 h The amount of H2S present in the vapor space was determined by measuring the vapor space hydrogen sulfide levels according to ASTM D5705-03.
The test procedure was modified by running at temperatures other than 60 C. A one-gallon sample was divided into multiple 500 milliliter samples for testing. The treated containers were pre-dosed with Compounds A-C and then the fluid being tested was poured into the container.
In each example, the dose ratio was the number used to determine the ppm treat rate for the sample. For table 1 the untreated sample resulted in a vapor space hydrogen sulfide measurement of 800 ppm. A dose ratio of 0.2 indicates the sample was treated with 160 ppm of additive. A dose ratio of 0.3 indicates that the sample was treated with 240 ppm of additive.
This data demonstrates that the presence of the alpha-amino ether scavenger reduced the H2S in the hydrocarbon fluids in a relatively short amount of time and continued to reduce the H2S the longer the sample was exposed to the alpha-amino ether prior to testing.
While this invention may be embodied in many different forms, there are shown in the drawings and described in detail herein specific preferred embodiments of the invention. The present disclosure is an exemplification of the principles of the invention and is not intended to limit the invention to the particular embodiments illustrated. Furthermore, the invention encompasses any possible combination of some or all of the various embodiments described herein and incorporated herein.
The above disclosure is intended to be illustrative and not exhaustive. This description will suggest many variations and alternatives to one of ordinary skill in this art. All these alternatives and variations are intended to be included within the scope of the claims where the term "comprising" means "including, but not limited to". Those familiar with the art may recognize other equivalents to the specific embodiments described herein which equivalents are also intended to be encompassed by the claims.
All ranges and parameters disclosed herein are understood to encompass any and all subranges subsumed therein, and every number between the endpoints. For example, a stated range of "1 to 10" should be considered to include any and all subranges between (and inclusive of) the minimum value of 1 and the maximum value of 10; that is, all subranges beginning with a minimum value of 1 or more, (e.g. 1 to 6.1), and ending with a maximum value of 10 or less, (e.g. 2.3 to 9.4,3 to 8,4 to 7), and finally to each number 1, 2, 3, 4, 5, 6, 7, 8, 9, and 10 contained within the range.
This completes the description of the preferred and alternate embodiments of the invention. Those skilled in the art may recognize other equivalents to the specific embodiment described herein which equivalents are intended to be encompassed by the claims attached hereto.
Claims (6)
1. A method of scavenging hydrogen sulfide from a hydrocarbon fluid having a vapor phase, comprising contacting the hydrocarbon fluid with an effective amount of a composition comprising a hydrogen sulfide scavenger, wherein the effective amount of hydrogen sulfide scavenger is sufficient to reduce the hydrogen sulfide found in the vapor phase, and wherein the reaction product of the hydrogen sulfide scavenger and the hydrogen sulfide remain soluble in the hydrocarbon fluid, wherein the hydrogen sulfide scavenger comprises the product of a reaction between a secondary amine and a formaldehyde equivalent, wherein the molar ratio of the amine to the formaldehyde equivalent in the reaction is from 1.2:1 to 1:1.2, and the product comprises 10-25% of a compound of formula A, 10-25% of a compound of formula B, and 50-80%
of a compound of formula C, wherein percentages are based on molarity, wherein:
formula A is:
formula B is: and formula C
wherein each R is independently selected from the group consisting of methyl, ethyl, propyl, n-butyl, tert-butyl, cyclopentyl, cyclohexyl and phenyl.
of a compound of formula C, wherein percentages are based on molarity, wherein:
formula A is:
formula B is: and formula C
wherein each R is independently selected from the group consisting of methyl, ethyl, propyl, n-butyl, tert-butyl, cyclopentyl, cyclohexyl and phenyl.
2. The method of claim 1, wherein the compound of formula A is N,N,N',N'-tetrabutylmethanediamine, the compound of formula B is N,N'-oxybis(methylene)bis(N,N-dibutylamine), and the compound of formula C is N,N' (methylenebis(oxy)bis(methylene))bis(N,N-dibutylamine).
3. The method of claim 1 or 2, wherein the reaction product of the composition comprising the hydrogen sulfide scavenger and the hydrogen sulfide do not form a separate fluid layer.
4. The method of any one of claims 1 to 3, wherein the formaldehyde equivalent is formaldehyde.
5. The method of any one of claims 1 to 4, wherein the hydrocarbon fluid is a liquid.
6. The method of any one of claims 1 to 3, wherein the formaldehyde equivalent is selected from the group consisting of formaldehyde, paraformaldehyde, and s-trioxane.
Applications Claiming Priority (3)
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| US12/836,037 US20120012507A1 (en) | 2010-07-14 | 2010-07-14 | Use of alpha-amino ethers for the removal of hydrogen sulfide from hydrocarbons |
| US12/836,037 | 2010-07-14 | ||
| PCT/US2011/043793 WO2012009396A2 (en) | 2010-07-14 | 2011-07-13 | Use of alpha-amino ethers for the removal of hydrogen sulfide from hydrocarbons |
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| CA2805404A1 CA2805404A1 (en) | 2012-01-19 |
| CA2805404C true CA2805404C (en) | 2018-11-27 |
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| CA2805404A Active CA2805404C (en) | 2010-07-14 | 2011-07-13 | Use of alpha-amino ethers for the removal of hydrogen sulfide from hydrocarbons |
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| US (1) | US20120012507A1 (en) |
| EP (1) | EP2593535A4 (en) |
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| US8663457B2 (en) * | 2011-11-23 | 2014-03-04 | General Electric Company | Methods and compounds for improving sulfide scavenging activity |
| US9108899B2 (en) | 2011-12-30 | 2015-08-18 | General Electric Company | Sulfide scavengers, methods for making and methods for using |
| US9278307B2 (en) | 2012-05-29 | 2016-03-08 | Baker Hughes Incorporated | Synergistic H2 S scavengers |
| CA2889622C (en) * | 2012-12-19 | 2021-02-02 | Nalco Company | Functionalized hydrogen sulfide scavengers |
| BR112015011232B1 (en) | 2012-12-19 | 2021-07-06 | Ecolab Usa Inc | compression treatment method for eliminating hydrogen sulfide in a production fluid |
| WO2014100052A1 (en) * | 2012-12-19 | 2014-06-26 | Nalco Company | Scavenging hydrogen sulfide |
| CN104955800B (en) | 2013-01-30 | 2018-11-06 | 艺康美国股份有限公司 | Hydrogen sulfide scavenger |
| US9663390B2 (en) | 2013-05-10 | 2017-05-30 | Ecolab Usa Inc. | Reduction of hydrogen sulfide and/or malodor gassing from water via the addition of peroxyacetic acid/hydrogen peroxide product |
| US9719030B2 (en) | 2013-06-27 | 2017-08-01 | Ecolab Usa Inc. | Epoxide-based hydrogen sulfide scavengers |
| US9273254B2 (en) | 2013-12-20 | 2016-03-01 | Ecolab Usa Inc. | Amino acetals and ketals as hydrogen sulfide and mercaptan scavengers |
| US9458393B2 (en) | 2014-04-15 | 2016-10-04 | Ecolab Usa Inc. | Hydantoins as hydrogen sulfide and mercaptan scavengers |
| AU2016250539B2 (en) | 2015-04-22 | 2020-06-11 | Championx Usa Inc. | Development of a novel high temperature stable scavenger for removal of hydrogen sulfide |
| WO2017044248A1 (en) | 2015-09-08 | 2017-03-16 | Ecolab Usa Inc. | Hydrogen sulfide scavengers |
| US10513662B2 (en) | 2017-02-02 | 2019-12-24 | Baker Hughes, A Ge Company, Llc | Functionalized aldehydes as H2S and mercaptan scavengers |
| CN110573232A (en) * | 2017-05-12 | 2019-12-13 | 株式会社可乐丽 | Sulfur-containing compound removal device and sulfur-containing compound removal method |
| WO2018218641A1 (en) * | 2017-06-02 | 2018-12-06 | General Electric Company | Method of mitigation of tramp amines in application of h2s scavengers |
| EP3652274A1 (en) | 2017-07-13 | 2020-05-20 | Ecolab USA, Inc. | Method of removing a sulfur containing compound by adding a composition |
| EP3914676A1 (en) | 2019-01-23 | 2021-12-01 | ChampionX USA Inc. | Complete removal of solids during hydrogen sulfide scavenging operations using a scavenger and a michael acceptor |
| US20240110091A1 (en) | 2022-09-21 | 2024-04-04 | Championx Usa Inc. | Compositions and methods for scavenging sulfur-containing compounds |
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| US4057403A (en) * | 1973-10-29 | 1977-11-08 | Fluor Corporation | Gas treating process |
| US4405582A (en) * | 1982-01-18 | 1983-09-20 | Exxon Research And Engineering Co. | Process for selective removal of H2 S from mixtures containing H22 using diaminoether solutions |
| US4556546A (en) * | 1983-05-04 | 1985-12-03 | Air Products And Chemicals, Inc. | Bis tertiary amino alkyl derivatives as solvents for acid gas removal from gas streams |
| US4618481A (en) * | 1985-08-30 | 1986-10-21 | Exxon Research And Engineering Co. | Absorbent composition containing a severely hindered amino compound and an amine salt and process for the absorption of H2 S using the same |
| CA2007965C (en) * | 1989-02-13 | 1996-02-27 | Jerry J. Weers | Suppression of the evolution of hydrogen sulfide gases from petroleum residua |
| CA2017047C (en) * | 1989-08-01 | 1999-08-17 | Jerry J. Weers | Method of scavenging hydrogen sulfide from hydrocarbons |
| CA2148849A1 (en) * | 1994-06-23 | 1995-12-24 | Kishan Bhatia | Method of treating sour gas and liquid hydrocarbons |
| NO982505L (en) * | 1997-06-04 | 1998-12-07 | Nalco Exxon Energy Chem Lp | Composition and process for desulfurization of gaseous or liquid hydrocarbons, aqueous systems and mixtures thereof |
| US20020157989A1 (en) * | 2001-04-25 | 2002-10-31 | Clearwater, Inc. | Treatment of hydrocarbons Containing Sulfides |
| KR101384413B1 (en) * | 2005-08-09 | 2014-04-10 | 엑손모빌 리서치 앤드 엔지니어링 컴퍼니 | Alkylamino alkyloxy (alcohol) monoalkyl ether for acid gas scrubbing process |
| RU2349627C2 (en) * | 2005-10-27 | 2009-03-20 | Ахматфаиль Магсумович Фахриев | Hydrogen sulphide and/or low-molecular mercaptan remover and method of using it |
| CN102144019A (en) * | 2008-09-02 | 2011-08-03 | 通用电气公司 | Process for removing hydrogen sulfide in crude oil |
| US9394396B2 (en) * | 2011-06-21 | 2016-07-19 | Baker Hughes Incorporated | Hydrogen sulfide scavenger for use in hydrocarbons |
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Also Published As
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| JP2013531728A (en) | 2013-08-08 |
| WO2012009396A3 (en) | 2012-05-18 |
| CA2805404A1 (en) | 2012-01-19 |
| CN103403129B (en) | 2015-05-20 |
| EP2593535A2 (en) | 2013-05-22 |
| JP5890409B2 (en) | 2016-03-22 |
| RU2563633C2 (en) | 2015-09-20 |
| BR112013000890A2 (en) | 2016-05-17 |
| EP2593535A4 (en) | 2014-04-23 |
| SG187078A1 (en) | 2013-02-28 |
| KR20130047739A (en) | 2013-05-08 |
| CN103403129A (en) | 2013-11-20 |
| MX2013000507A (en) | 2013-02-27 |
| RU2013102414A (en) | 2014-08-20 |
| AR082165A1 (en) | 2012-11-14 |
| WO2012009396A2 (en) | 2012-01-19 |
| US20120012507A1 (en) | 2012-01-19 |
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