WO2015173253A2 - Procédé et appareil de purification du gaz naturel - Google Patents

Procédé et appareil de purification du gaz naturel Download PDF

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Publication number
WO2015173253A2
WO2015173253A2 PCT/EP2015/060495 EP2015060495W WO2015173253A2 WO 2015173253 A2 WO2015173253 A2 WO 2015173253A2 EP 2015060495 W EP2015060495 W EP 2015060495W WO 2015173253 A2 WO2015173253 A2 WO 2015173253A2
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Prior art keywords
acid
previous
liquid solution
metal
chelating
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WO2015173253A3 (fr
Inventor
Marco Johannes Gerardus LINDERS
Robert Christiaan Franciscus DE KLER
Earl Lawrence Vincent Goetheer
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Nederlandse Organisatie voor Toegepast Natuurwetenschappelijk Onderzoek TNO
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Nederlandse Organisatie voor Toegepast Natuurwetenschappelijk Onderzoek TNO
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Publication of WO2015173253A3 publication Critical patent/WO2015173253A3/fr
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    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D53/00—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols
    • B01D53/14—Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases, aerosols by absorption
    • B01D53/1456—Removing acid components
    • B01D53/1462—Removing mixtures of hydrogen sulfide and carbon dioxide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2251/00—Reactants
    • B01D2251/90—Chelants
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/10—Inorganic absorbents
    • B01D2252/103—Water
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/202—Alcohols or their derivatives
    • B01D2252/2021—Methanol
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/202—Alcohols or their derivatives
    • B01D2252/2023—Glycols, diols or their derivatives
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B01D2252/20405—Monoamines
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B01D2252/20436—Cyclic amines
    • B01D2252/20447—Cyclic amines containing a piperazine-ring
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B01D2252/20436—Cyclic amines
    • B01D2252/20457—Cyclic amines containing a pyridine-ring
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B01D2252/20478—Alkanolamines
    • B01D2252/20484—Alkanolamines with one hydroxyl group
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • B01D2252/20494—Amino acids, their salts or derivatives
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/50—Combinations of absorbents
    • B01D2252/504—Mixtures of two or more absorbents
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/60—Additives
    • B01D2252/604—Stabilisers or agents inhibiting degradation
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2256/00—Main component in the product gas stream after treatment
    • B01D2256/24—Hydrocarbons
    • B01D2256/245—Methane
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/30—Sulfur compounds
    • B01D2257/304—Hydrogen sulfide
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/30—Sulfur compounds
    • B01D2257/306—Organic sulfur compounds, e.g. mercaptans
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/30—Sulfur compounds
    • B01D2257/308—Carbonoxysulfide COS
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/40—Nitrogen compounds
    • B01D2257/406—Ammonia
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/40—Nitrogen compounds
    • B01D2257/408—Cyanides, e.g. hydrogen cyanide (HCH)
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2257/00—Components to be removed
    • B01D2257/50—Carbon oxides
    • B01D2257/504—Carbon dioxide
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02C—CAPTURE, STORAGE, SEQUESTRATION OR DISPOSAL OF GREENHOUSE GASES [GHG]
    • Y02C20/00—Capture or disposal of greenhouse gases
    • Y02C20/40—Capture or disposal of greenhouse gases of CO2

Definitions

  • the invention is in the field of natural gas purification.
  • the invention is directed to a method for absorption of CO2 and H2S from natural gas.
  • Natural gas is formed over a period of thousands of years by a natural process of pressurizing and heating underground layers of plants. Natural gas can be extracted from so called gas fields and can be used for a variety of purposes. Typically, it is used as a fossil energy source in for example vehicles or electricity generators. Prior to its use in such
  • composition and pressure of methane comprising natural gas is amongst others dependent on the gas field it originates from. Pressures are typically 80-200 bar and although methane is the major component, partial pressures of CO2 up to 50 bar and H2S up to 30 bar can be found. Hence, effective CO2 and H2S removal from natural gas is of key importance prior to its use.
  • the CO2 and H2S can be removed by a variety of processes, of which most concern multiple-step processes.
  • methane comprising gas streams contaminated with CO2 and H2S can be washed under high pressure by liquids comprising physical solvents. Due to a difference in solubility between methane and
  • the contaminants i.e. CO2 and H2S
  • the physical solvents can be regenerated by reducing the pressure to liberate the CO2 and H2S.
  • H2S can not be emitted into air and has to be treated separately in for instance a Claus process. In such a process, H2S is converted into elementary sulfur.
  • a major drawback of this method is the high investment and maintenance costs of Claus plants.
  • a second drawback is the limited absorption capacity of the physical solvent, especially under lower partial pressure of the contaminants, that
  • the natural gas stream is purified by subsequent absorption steps. For instance, first H2S is converted to elementary sulfur by a redox reaction with Fe 3+ EDTA and subsequently in a second step, CO2 is physically or chemically absorbed.
  • US-A-4400368 and US-A-4091073 both describe removing H 2 S and CO2 from methane comprising gas streams in a single procedure by contacting the gas with a liquid solution comprising a metal, a chelating ligand, a stabilizer as well as an absorbent for CO2.
  • the absorbents are physical absorbents for CO2 and therefore less effective at absorbing CO2 at low (partial) pressures. It is desirable that the absorption of CO2 is more effective at these low (partial) pressures.
  • the present invention is directed to a method for absorbing CO2 and H2S from a methane comprising gas stream by contacting said stream with a liquid solution that comprises a physical solvent, a non-chelating amine, a metal, a chelating ligand and a stabilizer.
  • the liquid solution may be referred to as a lean liquid solution prior to absorption and as an enriched liquid solution after absorption of CO2 and H2S.
  • the present invention is based on three absorption principles: physical absorption of CO2 by a physical solvent, chemical absorption of CO2 by a non-chelating amine and absorption of H2S by converting this into elementary sulfur. These three absorption principles occur in one process and in one liquid solution.
  • Figure 1 is a diagram showing the relation between CO2 partial pressure and the concentration of CO2 absorbed in a solvent.
  • FIG. 2 is a schematic representation of an apparatus in accordance with the present invention.
  • FIG. 3 is a schematic representation of another embodiment of an apparatus in accordance with the present invention.
  • FIG. 4 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • FIG. 5 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • Figure 6 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • FIG. 7 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • Figure 8 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • Figure 9 is a schematic representation of yet another embodiment of an apparatus in accordance with the present invention.
  • Figure 10 is a schematic representation of yet another
  • the invention aims at the purification of natural gas, it will be appreciated that the invention is also applicable for any other methane comprising gas stream at elevated pressures.
  • the gas stream may have an elevated pressure of 30 to 200 bar, preferably 50 to 120 bar, more preferably 60 to 100 bar.
  • H2S is absorbed in the liquid solution by a redox reaction with a metal (M x ).
  • a chelating ligand (L) is present to solubilize the metal.
  • a chelating ligand a ligand that comprises three or more, typically 4 to 8, functional groups that may simultaneously bind to the metal of the present invention.
  • a non-chelating amine is meant an amine that comprises two or less functional groups that may simultaneously bind to the metal of the present invention.
  • Typical functional groups in this respect are amines, carboxylic acids, hydroxides, sulfides, phosphines and the like.
  • the metal and chelating ligand form a metal chelate complex (M X L) that reacts with the H2S in the gas stream, typically according to the following reaction scheme:
  • M X L is regained by a reaction of M ⁇ - ⁇ L with an oxygen containing gas, preferably air, according to the following reaction scheme:
  • CO2 is absorbed in a liquid solution via two complementary absorption principles: physical and chemical absorption.
  • Physical absorption is based on the absorption of CO2 in a physical solvent and is governed by Henry's law that describes a linear relation between the partial pressure of the gas and the amount of gas that is absorbed in the physical solvent. As a consequence, at high partial pressure, much gas is absorbed in the physical solvent. However, as the partial pressure decreases during the absorption step as a consequence of it being absorbed in the physical solvent, the amount of CO2 that is absorbed from the gas stream at the end stage of the absorption step will be lower. Therefore, at the end of the process, some CO2 typically remains in the gas stream. Although further removal of CO2 may be possible, this is typically not desirable, because such removal would cost large amounts of physical solvent, which may be both economically and ecologically undesirable.
  • Chemical absorption is based on the reaction between the chemical solvent and CO2.
  • the chemical solvent is a non-chelating amine. Chemical absorption is not governed by Henry's law nor is there a linear relation between partial pressure and absorbed gas concentration. Instead, it is characterized by a very high absorption at low partial pressure and by a saturation of the chemical solvent at high pressure.
  • the present invention exploits both principles to increase the overall effectiveness of CO2 absorption by combining a physical solvent and a non-chelating amine in a single liquid solution. Hence, the majority of CO2 is absorbed by physical absorption, without saturating the non-chelating amine, while at the end stage of the absorption process when partial CO2 pressure is low, the remaining CO2 is absorbed by the non-chelating amine.
  • the chemical absorption of CO2 by the chemical solvent is preferably effected by a non-chelating amine that is present in the liquid solution.
  • reaction scheme In the case non-hindered primary and secondary amines are used, the reaction of the CO2 in the gas stream with the non-chelating amine in the liquid solution typically proceeds according to the following reaction scheme:
  • reaction products remain dissolved in the liquid solution and a C02-rich solution is obtained.
  • the metal can be any metal or mixture thereof capable of oxidizing H2S.
  • the metal can be added to the process in a reactive form, i.e.
  • the metal first has to be activated before it can oxidize H2S.
  • the metal is a cation selected from the group consisting of Fe, V, Cu, Zn, Mn, Mg and combinations thereof.
  • different oxidation states can be used, e.g. Fe 2+ /Fe 3+ or V 4+ /V 5+ .
  • a chelating ligand is defined as an organic compound containing more than one functional groups that are capable of forming a bond with the metal in such a way that more than one coordination bonds are formed between the said organic compound and the metal.
  • the chelating ligand contains one or more amine groups and one or more oxygen-containing groups such as alcohols and carboxylic acids.
  • the chelating ligand can be added as purely organic compound or as a salt thereof. Moreover, it can be added as a complex formed with the metal.
  • the chelating ligand is selected from the group consisting of nitrilotriacetic acid (NTA),
  • EDTA ethylenediaminetetraacetic acid
  • HEDTA hydroxyethyl)ethylenediamine triacetic acid
  • DTPA pentetic acid
  • TAA triethanolamine
  • MIDA 1,2- cyclohexylenedinitrilotetraacetic acid
  • MIDA 1,3-propanediaminetetraacetic acid
  • BDTA 1,4- butanediaminetetraactetate
  • HEDP etidronic acid
  • a stabilizer is present.
  • the stabilizer is a radical scavenger.
  • Such a radical scavenger is typically capable of reacting with and de-activating radicals.
  • the stabilizer is selected from the group consisting of thiodiglycolic acid, 3,3-thiodipropionic acid, sodium thiocyanate, sodium dithionite, ammonium thiosulfate, sodium thiosulfate, ⁇ , ⁇ -diethylhydroxylamine, thiourea, thiosemicarbazide, bisulphite, sodium benzoate, para-toluenesulfonic acid, potassium iodide, potassium bromide, potassium chloride, 2-propanol, 1-butanol, ethylene glycol, sodium formate, sucrose, sorbitol, nitrites, amino acids, aliphatic aldehydes, aryl sulfonic acids and combinations thereof.
  • amines can be lost from the process by evaporation. Therefore, amines with low or no vapor pressures are preferred, e.g. vapor pressures lower than 900 Pa at 25°C, preferably lower than 150 Pa at 25°C. Furthermore, amines can be lost by oxidation during the regeneration of the metal. Loss of amines should be avoided. Therefore, in a preferred embodiment of the present invention, the non-chelating amine is added as a salt thereof.
  • the non-chelating amine salt is preferably a salt with potassium or sodium, potassium being preferred.
  • the non-chelating amine is preferably an amino acid.
  • amino acid is defined as an organic compound which comprises at least one amine group and at least one acid group selected from carboxylic acid, phosphoric acid and sulfonic acid.
  • the acid groups can be bound to one and the same atom of the organic substance (as is the case with the natural occurring amino acids) or to different atoms.
  • the amino acid is selected from a group consisting of taurine, glycine, alanine, asparagine, glutamine, lysine, histidine and derivatives of these such as N-methylglycine, N-methylalanine and combinations thereof.
  • the non-chelating amine is an amine other than an amino acid.
  • Such a non-chelating amine may be a monoamine or polyamine and is preferably selected from the group consisting of the monoamines monoethanolamine (MEA) and 2 piperidine ethanol (PE), and the
  • polyamines piperazine and aminoethylpiperazine (AEP), and combinations thereof.
  • the non-chelating amine is regenerated by heating the liquid solution containing CO2. Such a heating step is preferably conducted after regenerating the metal by oxidation.
  • the pressure of the liquid solution may be reduced before this heating.
  • the physical solvent can be any solvent capable of absorbing CO2.
  • the physical solvent is selected from the group consisting of H2O, MeOH, polyethylene glycol, propylene carbonate, dimethyl carbonate (DMC), N-methyl-2-pyrrolidone, N-formyl morpholine, methyl cyanoacetate, polypropyleneglycol dimethylether
  • PPGDME polydimethylsiloxane
  • PDMS polydimethylsiloxane
  • PFPE perfluoropolyether
  • the lean liquid solution i.e. the liquid solution prior to the absorption of CO2 and H2S
  • the absorption temperature i.e. the temperature whereby the absorption is taking place, is between 20 and 60 °C.
  • the content of the non-chelating amine in the lean liquid solution may be less than 30 wt%, preferably less than 20 wt%, most preferably less than 10 wt%, based on the total weight of the liquid solution.
  • the method of the invention may comprise the further step of removing gas from the liquid solution, such as CO2 and/or methane. Such release may be achieved by decreasing the pressure above the liquid solution. This step can be suitably conducted in one or more flash vessels.
  • the method may further comprise the step of sulfur removal from the liquid solution, e.g. using a plate settler.
  • the method of the invention may further comprise a metal regeneration step by introducing an oxygen containing gas such as air in the solution, as already described above.
  • a stripper may be used to remove CO2 from the non- chelating amine and/or further remove CO2 from the physical solvent.
  • the present invention allows for a simplified natural gas purifying apparatus, viz. only one absorption column is required for the absorption of both CO2 and H2S from the gas stream.
  • Such an apparatus comprises an absorption column.
  • the absorption column comprises a first inlet (1), preferably located at the bottom part of the absorption column, through which the gas stream may be introduced and it comprises a second inlet (2), preferably located at the top part of the absorption column, through which the liquid solution may be introduced. It furthermore contains a volume (3) where said gas stream contacts the lean liquid solution.
  • the absorption column furthermore comprises a first outlet (4), preferably located at the top part of the absorption column, through which the purified (or upgraded) gas stream, i.e.
  • a gas stream containing less CO2 and H2S compared to the gas stream that was introduced into the absorption column may leave and it comprises a second outlet (5), preferably located at the bottom part of the absorption column through which the enriched liquid solution may leave.
  • the apparatus may further comprise one or more flash vessels (in order to deal with the elevated pressure of the gas to be used), which are typically connected in series with the absorption vessel.
  • the apparatus may further comprise a gas injection vessel such as a flotation vessel, a flocculation vessel or a bubble column (for
  • the absorption column is connected to the one or more flash vessels, the last flash vessel is connected to the gas injection vessel, the gas injection vessel is connected to the liquid-solid separator and the liquid-solid separator is connected to the stripper.
  • the gas injection vessel is preferably a flocculation vessel to enhance sulfur removal.
  • the liquid- solid separator may also change places with the gas injection vessel (such that the liquid-solid separator will be connected to the absorption column and the gas injection vessel will be connected to the stripper).
  • said second outlet (5) is connected to a first flash vessel, wherein the pressure of the enriched liquid solution may be reduced.
  • the flash vessel comprises an inlet (6), through which the enriched liquid solution may be introduced. It furthermore comprises a first outlet (7), preferably located at the bottom, through which the enriched liquid solution at a reduced pressure may leave and a second outlet, preferably located at the top, through which vapor and gases such as methane and CO2 may leave.
  • said first outlet (7) is further connected to a liquid-solid separator (e.g. a plate settler), where the sulfur is removed from the liquid solution.
  • the liquid-solid separator comprises a first inlet (8) through which the liquid solution rich in CO2 and sulfur may be introduced. It furthermore comprises a first outlet (9) through which the sulfur may leave and it comprises a second outlet (10) through which the liquid solution rich in CO2 may leave.
  • said second outlet (10) is further connected to a gas injection vessel which acts as a regenerator of the reduced metal complex M ⁇ L.
  • a gas injection vessel is a vessel that is suitable for injecting a gas such as oxygen into the vessel, e.g. a flotation vessel or bubble column.
  • Said gas injection vessel comprises a first inlet (11), preferably located at the top part of the gas injection vessel, through which the liquid solution rich in reduced metal may be introduced. It furthermore comprises a second inlet (12), preferably located at the bottom part, through which oxygen, preferably oxygen in air may be introduced. It furthermore comprises a volume of oxidation (15) wherein said oxygen may contact said liquid solution rich in reduced metal.
  • said gas injection vessel comprises a first outlet (13), preferably located at the top part through which unreacted oxygen, preferably unreacted oxygen in air may leave and a second outlet (14), preferably located at the bottom through which said liquid solution rich in CO2 and the oxidized metal (i.e. regenerated metal) may leave.
  • the liquid-solid separator and the gas injection vessel have changed places, such that the gas injection vessel is placed between and connected to the (last) flash vessel and the liquid-solid separator (see figure 9).
  • the stripper furthermore comprises a volume (17) wherein said liquid solution rich in CO2 is heated. As a consequence the CO2 leaves the liquid solution.
  • said stripper comprises a first outlet (18), preferably located at the top part through which CO2 may leave and a second outlet (19), preferably located at the bottom through which said liquid solution stripped of CO2 may leave.
  • liquid-solid separator and the gas injection vessel have changed places (such that the gas injection vessel is placed between and connected to the (last) flash vessel and the liquid-solid separator) and the stripper will be connected to the liquid-solid separator (see figure 9).
  • the apparatus there is a second flash vessel, connected in series to the first flash vessel to further reduce the pressure of the enriched solution.
  • the second flash vessel comprises an inlet (20), through which the enriched liquid solution may be introduced. It furthermore comprises a first outlet (21), preferably located at the bottom, through which the enriched liquid solution at a reduced pressure may leave and a second outlet (22), preferably located at the top, through which vapor and gases such as methane and CO2 may leave.
  • said first outlet (21) is then connected to the liquid- solid separator via its inlet (8).
  • the metal may be regenerated before the sulfur is separated from the enriched liquid solution.
  • the outlet (7) of the first flash vessel, or optionally the outlet (21) of the second flash vessel is connected to the gas injection vessel via its inlet (11).
  • the second outlet of the gas injection vessel is then connected to the liquid-solid separator via its inlet (8) and the second outlet (10) of the liquid-solid separator is then connected to the stripper via its inlet (16).
  • the apparatus comprises an absorption column that is divided into two sections or two columns.
  • the first section or column comprises the first inlet (1; for gas to enter) and second outlet (5; for liquid to leave), while the second section or column comprises the second inlet (2; for liquid to enter) and first outlet (4; for gas to leave).
  • the two sections or columns are connected via an outlet (23) (typically located at the top of the first section or column) and an inlet (24) (typically located at the bottom of the second column or section) through which the methane comprising gas stripped from H2S may pass.
  • the apparatus in this embodiment may thus comprise a first section or column which comprises a volume (3a) where the H2S may be absorbed and part of the CO2 may be absorbed and a second section or column which comprises a volume (3b) where the remaining part of the CO2 may be absorbed.
  • the absorption column may comprise a third outlet (25) located at the bottom part of the second section or column and a third inlet (26) located at the top part of the first section or column.
  • the third outlet (25) is connected to the third inlet (26) and to an inlet (27) of an additional flash vessel, which flash vessel is connected through its outlet (28) to the inlet (16) of the stripper.
  • part of the liquid solution rich in CO2 may go to the second section or column via the third inlet (26) and another part of the liquid solution rich in CO2 may go to the additional flash vessel via its inlet (27).
  • the additional flash vessel may furthermore comprise a second outlet (29) through which vapor and gases such as methane and CO2 may leave.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Analytical Chemistry (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Gas Separation By Absorption (AREA)

Abstract

L'invention concerne un procédé pour absorber le CO2 et le H2S d'un flux gazeux contenant du méthane, par mise en contact du flux avec une solution liquide qui contient un solvant physique, une amine non-chélatrice, un métal, un ligand chélateur et un stabilisateur.
PCT/EP2015/060495 2014-05-12 2015-05-12 Procédé et appareil de purification du gaz naturel Ceased WO2015173253A2 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP14167949 2014-05-12
EP14167949.8 2014-05-12

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WO2018076055A1 (fr) * 2016-10-25 2018-05-03 Intelligas Renewable Fuels Limited Procédé et appareil de séparation de composants d'un flux de gaz
CN110560020A (zh) * 2019-09-24 2019-12-13 山东泰和水处理科技股份有限公司 一种活性炭的回收及利用方法

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Publication number Priority date Publication date Assignee Title
WO2018076055A1 (fr) * 2016-10-25 2018-05-03 Intelligas Renewable Fuels Limited Procédé et appareil de séparation de composants d'un flux de gaz
CN110560020A (zh) * 2019-09-24 2019-12-13 山东泰和水处理科技股份有限公司 一种活性炭的回收及利用方法
CN110560020B (zh) * 2019-09-24 2022-03-04 山东泰和水处理科技股份有限公司 一种活性炭的回收及利用方法

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