Process for removing acid gases with hindered amines and amino acids

Claim 2

A process for the removal of acidic components from a gaseous stream, which comprises contacting said gaseous stream (1) in an absorption step with an aqueous absorbing solution comprising (a) a basic alkali metal salt or hydroxide selected from the group consisting of alkali metal bicarbonates, carbonates, hydroxides, borates, phosphates and their mixtures, and (b) an activator for said basic alkali metal salt or hydroxide comprising (i) at least one sterically hindered amine containing at least one secondary amino group attached to either a secondary or tertiary carbon atom or a primary amino group attached to a tertiary carbon atom, said sterically hindered amine being a member selected from the group consisting of amino-ethers, aminoalcohols, di- and triamines, and (ii) an aminoacid having 4 to 8 carbon atoms; and (2) in a desorption and regeneration step desorbing at least a portion of the absorbed acidic components from said absorbing solution.

Claim 3

The process of claim 1 wherein said acidic component includes CO 2 .

Claim 4

The process of claim 1 wherein said acidic component includes CO 2 and H 2 S.

Claim 5

The process of claim 1 wherein said sterically hindered amine is a piperazine derivative or a cycloaliphatic diamine.

Claim 6

The process of claim 1 wherein said aminoacid is a sterically hindered aminoacid containing at least one secondary amino group attached to either a secondary or tertiary carbon atom or a primary amino group attached to a tertiary carbon atom and being free of any hdyroxy groups.

Claim 7

The process of claim 1 wherein said aminoacid is a tertiary aminoacid which does not contain any hydroxyl groups.

Claim 8

The process of claim 1 wherein said basic alkali metal salt or hydroxide is K 2 CO 3 , and said activator is N-cyclohexyl-1,3-propanediamine and said aminoacid is pipecolinic acid.

Claim 9

The process of claim 1 wherein said aminoacid is a member selected from the group consisting of pipecolinic acid, N,N-dimethyl glycine, 3-amino-3-methyl butyric and 2-amino-2-methylbutyric acid.

Claim 10

A process for the removal of CO 2 from a gaseous stream, which comprises contacting said gaseous stream (1) in an absorption step with an aqueous absorbing solution comprising (a) a basic salt comprising K 2 CO 3 and (b) an activator for said basic salt comprising (i) a sterically hindered amine selected from the group consisting of N-cyclohexyl-1,3-propanediamine, N 1 (1,2-dimethyl-2-hydroxyethyl)-2-methyl-1,2-propanediamine, 2-methylpiperazine and 2,5-dimethylpiperazine, and (ii) an aminoacid selected from the group consisting of pipecolinic acid, N,N-dimethyl glycine, 3-amino-3-methyl butyric acid and 2-amino-2-methyl-butyric acid; and (2) in a desorption and regeneration step desorbing at least a portion of the absorbed CO 2 from said absorbing solution.

Claim 11

A process for the removal of CO 2 from a gaseous stream, which comprises contacting said gaseous stream (1) in an absorption step with an aqueous absorbing solution comprising (a) a basic salt comprising K 2 CO 3 and (b) an activator for said basic salt comprising (i) a sterically hindered amine selected from the group consisting of N-cyclohexyl-1,3-propanediamine, N 1 (1,2-dimethyl-2-hydroxyethyl)-2-methyl-1,2-propanediamine, 2-methylpiperazine and 2,5-dimethylpiperazine, and (ii) an aminoacid selected from the group consisting of pipecolinic acid, N,N-dimethyl glycine, 3-amino-3-methyl butyric acid and 2-amino-2-methyl-butyric acid; and (2) in a desorption and regeneration step desorbing at least a portion of the absorbed CO 2 from said absorbing solution.

Claim 12

The process of claim 9 wherein said sterically hindered amine is N-cyclohexyl-1,3-propanediamine and said amino acid is pipecolinic acid.

Claim 13

The process of claim 1 wherein the temperature of the absorbing solution during the absorption step is in the range of from about 25° to about 200° C., the pressures in the absorber ranges from about 5 to about 2000 psig and the partial pressure of the acid components in the feed stream ranges from about 0.1 to about 500 psia.

Claim 14

The process of claim 11 wherein the temperature of the absorbing solution during the regeneration step is in the range from about 25° to about 200° C. and at pressures ranging from about 16 to about 100 psia.

Claim 15

The process of claim 1 wherein the absorbing solution additionally includes additives selected from the group consisting of antifoaming agents, antioxidants and corrosion inhibitors.

Claim 16

The process of claim 9 wherein the temperature of the absorbing solution during the absorption step is in the range from about 25° to about 200° C., the pressures in the absorber range from about 5 to about 2000 psig and the partial pressures of the CO 2 in the feed stream is in the range from about 0.1 to about 500 psia.

Claim 17

The process of claim 14 wherein the temperature of the absorbing solution during the regeneration step is in the range from about 25° to about 200° C. and at pressures ranging from about 16 to about 100 psia.

Claim 18

The process of claim 9 wherein the absorbing solution additionally including additives selected from the group consisting of antifoaming agents, antioxidants and corrosion inhibitors.

Claim 19

A process for the removal of CO 2 from a gaseous stream which comprises, in sequential steps, (1) contacting the gaseous stream with an absorbing solution comprising (a) from about 10 to about 40 weight percent of potassium carbonate and (b) an activator system for the potassium carbonate comprising (i) from about 2 to about 20 weight percent of at least one sterically hindered amine containing at least one secondary amino group attached to either a secondary or tertiary carbon atom or a primary amino group attached to a tertiary carbon atom, said sterically hindered amines being members selected from the group consisting of aminoethers, aminoalcohols, di- and triamines, (ii) from about 2 to about 20 weight percent of an aminoacid having 4 to 8 carbon atoms, and (c) the balance of said absorbing solution being comprised of water, wherein said contacting is conducted at conditions whereby CO 2 is absorbed in said absorbing solution and the temperature of the absorbing solution is in the range from about 35° to about 150° C. and the pressure in the absorber is in the range from about 100 to about 1500 psig; and (2) regenerating said absorbing solution at conditions whereby CO 2 is desorbed from said absorbing solution, wherein the regeneration takes place at temperatures ranging from about 35° to about 150° C. and at pressures ranging from about 5 to about 100 psig.

Claim 20

A process for the removal of CO 2 from a gaseous stream which comprises, in sequential steps, (1) contacting the gaseous stream with an absorbing solution comprising (a) from about 10 to about 40 weight percent of potassium carbonate and (b) an activator system for the potassium carbonate comprising (i) from about 2 to about 20 weight percent of at least one sterically hindered amine containing at least one secondary amino group attached to either a secondary or tertiary carbon atom or a primary amino group attached to a tertiary carbon atom, said sterically hindered amines being members selected from the group consisting of aminoethers, aminoalcohols, di- and triamines, (ii) from about 2 to about 20 weight percent of an aminoacid having 4 to 8 carbon atoms, and (c) the balance of said absorbing solution being comprised of water, wherein said contacting is conducted at conditions whereby CO 2 is absorbed in said absorbing solution and the temperature of the absorbing solution is in the range from about 35° to about 150° C. and the pressure in the absorber is in the range from about 100 to about 1500 psig; and (2) regenerating said absorbing solution at conditions whereby CO 2 is desorbed from said absorbing solution, wherein the regeneration takes place at temperatures ranging from about 35° to about 150° C. and at pressures ranging from about 5 to about 100 psig.

Claim 21

The process of claim 17 wherein the sterically hindered amine is selected from the group consisting of N-cyclohexyl-1,3-propanediamine, N 1 (1,1-dimethyl-2-hydroxyethyl)-2-methyl-1,2-propanediamine, 2-methylpiperazine and 2,5-dimethylpiperazine.

Claim 22

The process of claim 18 wherein the amino-acid is selected from the group consisting of pipecolinic acid, N,N-dimethyl glycine, 3-amino-3-methyl butyric acid and 2-amino-2-methyl-butyric acid.

Claim 23

The process of claim 19 wherein the potassium carbonate content in the absorbing solution is in the range from about 20 to about 30 weight percent, the content of the sterically hindered amine is in the range from about 5 to about 15 weight percent and the content of the aminoacid is in the range from about 5 to about 15 weight percent.

Claim 24

The process of claim 17 wherein the absorbing solution additionally includes an additive selected from the group consisting of antifoaming agents, antioxidants and corrosion inhibitors.

Claim 25

The process of claim 17 wherein the absorbing solution from the regeneration step is recycled for use in the absorption step.

Claim 26

A process for the removal of CO 2 from a gaseous stream which comprises, in sequential steps, (1) contacting the gaseous stream with an absorbing solution comprising (a) from about 20 to about 30 weight percent of potassium carbonate, and (b) an activator system for the potassium carbonate, comprising (i) from about 5 to about 10 weight percent of N-cyclohexyl-1,3-propanediamine, (ii) from about 5 to about 15 weight percent of pipecolinic acid, and (c) the balance of the solution comprising water and additives selected from the group consisting of anti-foaming agents, antioxidants and corrosion inhibitors, wherein said contacting is conducted at conditions whereby CO 2 is absorbed in said absorbing solution and the temperature of the absorbing solution is in the range from about 35° to about 150° C. and the pressure in the absorber is in the range from about 100 to about 1500 psig; and (2) regenerating said absorbing solution at conditions whereby CO 2 is desorbed from said absorbing solution, wherein the regeneration takes place at temperatures ranging from about 35° to about 150° C. and at pressures ranging from about 5 to about 100 psig.

Claim 27

A process for the removal of CO 2 from a gaseous stream which comprises, in sequential steps, (1) contacting the gaseous stream with an absorbing solution comprising (a) from about 20 to about 30 weight percent of potassium carbonate, and (b) an activator system for the potassium carbonate, comprising (i) from about 5 to about 10 weight percent of N-cyclohexyl-1,3-propanediamine, (ii) from about 5 to about 15 weight percent of pipecolinic acid, and (c) the balance of the solution comprising water and additives selected from the group consisting of anti-foaming agents, antioxidants and corrosion inhibitors, wherein said contacting is conducted at conditions whereby CO 2 is absorbed in said absorbing solution and the temperature of the absorbing solution is in the range from about 35° to about 150° C. and the pressure in the absorber is in the range from about 100 to about 1500 psig; and (2) regenerating said absorbing solution at conditions whereby CO 2 is desorbed from said absorbing solution, wherein the regeneration takes place at temperatures ranging from about 35° to about 150° C. and at pressures ranging from about 5 to about 100 psig.

Claim 28

The process of claim 23 wherein the absorbing solution from the regeneration step is recycled for reuse in the absorption step.