WO2017108932A1 - Processus de récupération de co2 efficace et absorbant associé - Google Patents

Processus de récupération de co2 efficace et absorbant associé Download PDF

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Publication number
WO2017108932A1
WO2017108932A1 PCT/EP2016/082150 EP2016082150W WO2017108932A1 WO 2017108932 A1 WO2017108932 A1 WO 2017108932A1 EP 2016082150 W EP2016082150 W EP 2016082150W WO 2017108932 A1 WO2017108932 A1 WO 2017108932A1
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WO
WIPO (PCT)
Prior art keywords
absorbent composition
range
stream
koh
lean
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.)
Ceased
Application number
PCT/EP2016/082150
Other languages
English (en)
Inventor
Ytalo DAVILA
Kai Jürgen FISCHER
Eugene Marie Godfried Andre Van Kruchten
Eirik Falck DA SILVA
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Shell Internationale Research Maatschappij BV
Shell USA Inc
Original Assignee
Shell Internationale Research Maatschappij BV
Shell Oil Co
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij BV, Shell Oil Co filed Critical Shell Internationale Research Maatschappij BV
Publication of WO2017108932A1 publication Critical patent/WO2017108932A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • 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
    • B01D53/1475—Removing carbon dioxide
    • 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
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/62—Carbon oxides
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2251/00—Reactants
    • B01D2251/30—Alkali metal compounds
    • B01D2251/302—Alkali metal compounds of lithium
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2251/00—Reactants
    • B01D2251/30—Alkali metal compounds
    • B01D2251/304—Alkali metal compounds of sodium
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2251/00—Reactants
    • B01D2251/30—Alkali metal compounds
    • B01D2251/306—Alkali metal compounds of potassium
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2251/00—Reactants
    • B01D2251/60—Inorganic bases or salts
    • B01D2251/604—Hydroxides
    • 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
    • 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
    • B01D2252/202—Alcohols or their derivatives
    • B01D2252/2023—Glycols, diols or their derivatives
    • B01D2252/2026—Polyethylene glycol, ethers or esters thereof, e.g. Selexol
    • 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
    • B01D2252/2028—Polypropylene glycol, ethers or esters thereof
    • 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
    • Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
    • Y02A50/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE in human health protection, e.g. against extreme weather
    • Y02A50/20—Air quality improvement or preservation, e.g. vehicle emission control or emission reduction by using catalytic converters
    • 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 relates to a process for removing carbon dioxide from a feed gas stream.
  • the invention especially relates to a process which is very efficient in removing CO2, and in which the absorbent composition used can be regenerated .
  • CO2 absorbents are used, among others, to capture C02 from gas streams.
  • the captured C02 can be used for enhanced oil recovery by injecting it into an oil reservoir to achieve a higher oil recovery from the reservoir.
  • Other commercial uses of C02 are carbonation of beverages, the use as mild acidification chemical, and the use as cooling agent, e.g. "dry ice”.
  • CO2 may, for example, be removed from off gas produced during the combustion of fossil fuels. Additionally, natural gas generally comprises carbon dioxide which may cause corrosion problems when the natural gas is
  • CO2 may be removed by means of adsorption on solid substrates, chemical absorption, gas permeation, physical absorption, and combinations thereof.
  • physical absorbents are polycarbonate, polyethylene glycol dimethyl ether, and n-butane.
  • chemical absorbents are monoethanol amine (MEA) , diethanol amine (DEA) , methyl diethanol amine (MDEA) and diisopropanol amine (DIPA) .
  • MEA monoethanol amine
  • DEA diethanol amine
  • MDEA methyl diethanol amine
  • DIPA diisopropanol amine
  • the CO2 absorbents preferably are regenerable.
  • a disadvantage of amines is that they show thermal degradation. Another disadvantage is that some amines require accelerators.
  • the thermal decomposition of calcite may be performed in a lime kiln fired with oxygen in order to avoid an additional gas separation step.
  • a disadvantage of this procedure is the heat required for the thermal decomposition of the calcium precipitate .
  • US4406867 describes a process in which impurities such as hydrogen sulfide, carbon dioxide, carbonyl sulfide, sulfur dioxide and mercaptans are removed from gas streams. Water vapor may be simultaneously removed from the gas. A solution is used which has at least one of (a) hydroxides, carbonates and bicarbonates of sodium, potassium and lithium, and (b) liquid aliphatic polyhydric alcohol having a carbon to oxygen ratio of 1 to 5 and at least two oxygen thereof being separated by not more than the two sequential carbon atoms. After purifying the gas, the reaction
  • reaction product of CO2 and glycol solvent will decompose at 180 to 200 °C. Also mentioned is the decomposition of K 2 C0 3 to release C0 2 at 180 to 200 °C.
  • the invention relates to a process for removing carbon dioxide from a feed gas stream, which process comprises the steps :
  • lean absorbent composition comprises:
  • step (iii) optionally subjecting at least a part of the stream comprising C02 and H20 from step (ii) to
  • the present invention does not require an accelerator.
  • the absorbent composition does not show, or hardly shows, thermal degradation during the process of the present invention.
  • reaction products such as a reaction product of CO2 and glycol solvent which decomposes at 180 to 200 °C, and/or decomposition of K2CO3 to release CO2 at 180 to 200 °C as described in US4406867.
  • Another advantage is that deep C02 removal from the feed gas stream is obtained. Additionally, a stream
  • the obtained CO2 stream can thus be used for many applications. It can, for example be used for enhanced oil recovery. Moreover, it can, for example, be used as dry ice or in beverages, as it is non ⁇ toxic .
  • the invention relates to a process for removing carbon dioxide from a feed gas stream, which process comprises the steps :
  • lean absorbent composition comprises:
  • step (iii) optionally subjecting at least a part of the stream comprising C02 and H20 from step (ii) to condensation;
  • the feed gas stream from which CO2 is removed may be any carbon dioxide comprising gas. It may comprise hydrocarbons, especially methane. It may comprise nitrogen. It may be air. It may, for example, be or comprise natural gas. It may, for example, be off-gas produced during combustion. Off-gas produced during combustion may, for example, be off-gas produced during the combustion of fossil fuels; this may also be referred to as post-combustion gas.
  • the feed gas stream may comprise 100 ppm up to 50 wt% carbon dioxide, preferably 1 to 30 wt% carbon dioxide.
  • the gas When entering the process, the gas may have any suitable pressure; it may be at atmospheric pressure, at 2 bara, up to 100 bara.
  • the gas When entering the process, the gas may have any suitable temperature.
  • step (i) may be performed at relatively high temperatures, it will in most cases not be necessary to cool the feed gas stream. This is especially advantageous in case the feed gas is off-gas produced during combustion, more especially in case the feed gas is off-gas produced during the combustion of fossil fuels.
  • the lean absorbent composition used in step (i) comprises:
  • the lean absorbent composition used in step (i) may comprise other components than the components listed.
  • the amounts of all components in the lean absorbent composition are calculated on the total weight of the lean absorbent composition.
  • the amounts of all components in the lean absorbent composition used in step (i) add up to a total of 100 wt%.
  • step (i) a feed gas stream is contacted with a lean absorbent composition to absorb carbon dioxide and to form a carbon dioxide lean treated gas stream and a spent absorbent composition.
  • Step (i) preferably is performed in an
  • the absorber may have any suitable shape and size. It may, for example, be a (steel) column.
  • the feed gas stream and the lean absorbent composition are fed counter- currently to the absorber.
  • a C02 comprising feed gas stream is supplied at the bottom of the absorber.
  • a lean absorbent composition preferably is supplied at the top of the absorber or formed at the top or upper side of the absorber. Spent absorbent composition is removed from the absorber, preferably from the bottom of the absorber.
  • the lean absorbent composition comprises a hydroxide of an alkali metal, a polyhydric alcohol, and optionally water, and optionally diethylene glycol.
  • the lean absorbent composition comprises:
  • glycol preferably mono-ethylene glycol
  • the temperature in the absorber is in the range of from 50 - 200 °C, preferably 60 - 120 °C, more preferably 60 - 80 °C.
  • the pressure in the absorber may, for example, be in the range of from 1 to 100 bara. An exothermal reaction takes place in the absorber.
  • the lean absorbent composition comprises KOH
  • the following reactions take place in the absorber when a C02 comprising gas is contacted with the lean absorbent composition.
  • the polyhydric alcohol may serve as a solvent for one or more of the other components in the absorbent composition .
  • Spent absorbent composition is removed from the absorber, preferably from the bottom of the absorber.
  • Spent absorbent composition comprises polyhydric alcohol and alkali
  • the lean absorbent composition comprises KOH and MEG
  • the spent absorbent composition comprises KHC03 and MEG.
  • step (ii) absorbed C02 and H20 are removed from the spent absorbent composition with a gas or vapor stream to produce a regenerated absorbent composition and a stream comprising C02 and H20.
  • Step (ii) preferably is performed in a regenerator.
  • the regenerator may have any suitable shape and size. It may, for example, be a (steel) column.
  • step (i) is performed in an absorber and step (ii) is performed in a regenerator.
  • a spent absorbent composition is supplied to the
  • regenerator preferably at the bottom of the regenerator.
  • steam is injected into the regenerator, more preferably steam is injected at the bottom of the regenerator Most preferably steam is injected at the bottom of the regenerator using a live steam injector.
  • C02 and H20 are removed from the regenerator, preferably from the top of the regenerator.
  • Polyhydric alcohol comprising alkali metal which may contain a solution of an alkali metal salt of polyhydric alcohol, is removed from the regenerator,
  • the lean absorbent composition comprises KOH and a large amount of MEG
  • a composition comprising KMEG and MEG is removed from the regenerator.
  • C02 and H20 are removed in step (ii) by withdrawing a gas or vapor stream using a gas or vapor withdrawing device, preferably using a pump and/or an eductor
  • a gas or vapor withdrawing device preferably using a pump and/or an eductor
  • the removal of C02 and H20 may also be referred to as
  • the lean absorbent composition comprises KOH
  • the spent absorbent composition comprises KHC03, polyhydric alcohol, preferably alkylene glycol, more preferably mono-ethylene glycol (MEG) , and optionally H20 and optionally diethylene glycol.
  • the lean absorbent composition comprises KOH and a large amount of MEG
  • the following reaction takes place in the regenerator to which spent absorbent composition is fed:
  • H20 is continuously removed from the regenerator.
  • C02 is removed at a relatively high speed from the regenerator in order to reduce or to avoid the following reaction :
  • a high enough speed of C02 removal may be achieved by means of a gas or vapor withdrawing device, preferably a pump and/or an eductor.
  • a slip stream of the regenerated absorption medium may be taken away, and fresh lean absorption medium may be added to the system.
  • absorption medium may be taken away, and fresh lean
  • absorption medium may be added to the system. Additionally or alternatively, the slip stream may be treated with C02 :
  • the slip stream may be recycled.
  • the temperature in the regenerator is in the range of between 50 - 120 °C, preferably 60 - 100 °C, more preferably 75 - 100 °C.
  • the pressure in the regenerator may, for example, be in the range of from 2 - 300 mbara, preferably 20 - 200 mbara, more preferably 50 - 150 mbara.
  • C02 can be removed selectively from the regenerator. Water will be removed simultaneously during regeneration, but C02 can be easily removed from H20 by means of condensation. Salts comprising sulfur do not decompose at these low temperatures. The C02 product stream will thus not be contaminated with sulfur compounds and can be used in beverages, in enhanced oil recovery, etc. This is a major advantage as compared to the process described in US4406867.
  • polyhydric alcohol comprising alkali metal is removed from the regenerator, preferably from the bottom of the regenerator.
  • the withdrawn polyhydric alcohol comprising alkali metal is hygroscopic.
  • the lean absorbent composition in case, for example, the lean absorbent composition
  • step (iv) Preferably at least a part of the regenerated absorbent composition is recycled from step (ii) to step (i) .
  • step (iv) preferably water is added to at least a part of the regenerated absorbent composition from step (ii) .
  • Polyhydric alcohol comprising alkali metal is removed from the regenerator.
  • the composition comprises a hydroxide of an alkali metal.
  • the lean absorbent composition comprises KOH and a large amount of MEG
  • the composition removed from the regenerator comprises KMEG and MEG.
  • the KOH will react in the absorber with C02 and H20 to form KHC03.
  • water is removed, and a hygroscopic composition is obtained.
  • KOH will be formed again, which can be used again in the absorber.
  • KOH reacts in two steps in the absorber to form KHC03 it has a double capacity towards C02 as compared to K2C03.
  • step (iii) Preferably at least a part of the stream comprising C02 and H20 from step (ii) is subjected to condensation. This is step (iii) .
  • step (iii) When step (iii) is performed, preferably the condensed water from step (iii) is added to at least a part of the regenerated absorbent composition from step (ii) .
  • step (iv) is performed
  • water is added to at least a part of the
  • This water preferably is water obtained from condensation of the stream comprising C02 and H20 from step (iii) .
  • water preferably the condensed water from step (iii) , is added to at least a part of the
  • step (i) is performed in an absorption zone and the feed gas stream and the lean
  • the absorption zone may be an absorber which may have any suitable shape and size. It may, for example, be a (steel) column.
  • a hygroscopic composition comprising polyhydric alcohol comprising alkali metal for example comprising KMEG or comprising KMEG and MEG, is supplied to the absorption zone.
  • the hygroscopic composition comprising polyhydric alcohol comprising alkali metal is or comprises at least a part of the hygroscopic regenerated absorbent
  • composition from step (ii) Water, preferably water obtained from condensation of the stream comprising C02 and H20 from step (iii) , is fed to the absorption zone downstream of the entry of the hygroscopic composition comprising polyhydric alcohol comprising alkali metal. I.e. downstream with respect to the flow of the hygroscopic composition comprising
  • polyhydric alcohol comprising alkali metal, which preferably is regenerated absorbent composition.
  • a C02 comprising feed gas stream is supplied at the bottom of an absorber.
  • hygroscopic composition comprising polyhydric alcohol comprising alkali metal, for example comprising KMEG or comprising KMEG and MEG, is supplied at the top of the absorber. More preferably at least a part of the hygroscopic regenerated absorbent composition from step (ii) is supplied at the top of the absorber. Water, preferably the condensed water from step (iii) , is fed below the entry area of the hygroscopic composition. In this case lean absorbent
  • composition is formed in the absorber.
  • a composition comprising KOH and MEG may be formed.
  • the formed lean absorbent composition is lean with regard to C02 and may comprise some H20 from the gas stream.
  • Spent absorbent composition is removed from the absorber, preferably from the bottom of the absorber.
  • the water is added above the area from which spent absorbent composition is removed from the absorber. Preferably the water is added in the upper half of the absorber and below the entry area of the hygroscopic composition .
  • composition formed in the absorption zone which comprises: (a) in the range of from 0.5 to 60 wt% of a hydroxide of an alkali metal, preferably NaOH, KOH, LiOH, RbOH or CsOH, more preferably NaOH or KOH, most preferably KOH; and
  • the gas stream is contacted with the hygroscopic composition comprising polyhydric alcohol comprising alkali metal, which preferably is or comprises at least a part of the hygroscopic
  • the hygroscopic composition comprising polyhydric alcohol comprising alkali metal is first contacted with a C02 lean gas stream which may still comprise some H20. If present, most or all of the H20 is scavenged by the hygroscopic
  • composition comprising polyhydric alcohol comprising alkali metal. Thereafter the composition is still hygroscopic. Then water is fed to the hygroscopic composition comprising
  • polyhydric alcohol comprising alkali metal, and a C02 lean absorbent composition as described above is formed.
  • the lean absorbent composition is contacted with the feed gas stream, which comprises C02, and C02 is absorbed.
  • Spent absorbent composition is removed from the absorption zone .
  • Lean absorption medium or a hygroscopic composition comprising polyhydric alcohol comprising alkali metal may suitably be added to the absorption zone at a temperature in the range of between 50 - 200 °C.
  • Lean absorption medium may suitably be formed in the absorption zone at a temperature in the range of between 50 - 200 °C.
  • the present invention in which the C02 absorption may take place at relatively high temperatures and the
  • step (ii) of the process of the invention in which absorbed C02 and H20 are removed from spent absorbent composition with a gas or vapor stream.
  • An absorbent composition comprising water, mono-ethylene glycol, inorganic potassium salt, and KHC03 was subjected to regeneration in a vacuum distillation column consisting of more than 10 theoretical trays. A vacuum of 130 mbar absolute pressure was applied resulting in a range of bottom
  • Example 1 shows that even at temperatures as low as 90 °C, more than 50% of the carbon dioxide can be released.
  • An absorbent composition comprising water, mono-ethylene glycol and a salt was subjected to regeneration via stripping with an inert gas. Experiments were performed with different types of salt in the composition, see Table 1. The amount of C02 released was analyzed with titration of the residue samples. The amount of released C02 is presented as a
  • Salts such as CaC03 and K2C03 do not decompose at these low temperatures. Large amounts of such salts in the
  • regenerator can be avoided.
  • K2C03 can be reacted with C02 and H20 in the absorber to form KHC03.
  • a slip stream can be removed. Such a slip stream can be treated with C02 and then recycled.
  • Salts comprising sulfur do not decompose at these low temperatures. That is highly advantageous.
  • the C02 product stream will not be contaminated with sulfur compounds and can be used in beverages, in enhanced oil recovery, etc.

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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)
  • Health & Medical Sciences (AREA)
  • Biomedical Technology (AREA)
  • Environmental & Geological Engineering (AREA)
  • Gas Separation By Absorption (AREA)

Abstract

La présente invention concerne un processus destiné à retirer le dioxyde de carbone d'un flux de gaz d'alimentation. Un flux de gaz d'alimentation comprenant du CO2 est amené en contact avec une composition absorbante pauvre. La composition absorbante pauvre comprend (a) 0,5-60 % en poids d'un hydroxyde d'un métal alcalin, (b) 25-99,5 % en poids d'alcool polyhydrique, c) éventuellement 0,1-10 % en poids de diéthylène glycol et d) éventuellement 0,1-15 % en poids de H2O. Les CO2 et H2O absorbés sont éliminés de la composition absorbante usagée à l'aide d'un courant de gaz ou de vapeur à une température dans la plage comprise entre 50 et 120 °C. Les CO2 et H2O récupérés de l'étape (ii) peuvent être soumis à une condensation. De préférence, au moins une partie de la composition absorbante régénérée est recyclée de l'étape (ii) à l'étape (i). L'invention concerne en outre la composition absorbante. 20
PCT/EP2016/082150 2015-12-21 2016-12-21 Processus de récupération de co2 efficace et absorbant associé Ceased WO2017108932A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EP15201675 2015-12-21
EP15201675.4 2015-12-21

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WO2017108932A1 true WO2017108932A1 (fr) 2017-06-29

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Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3914376A4 (fr) * 2019-01-28 2023-02-15 Richardson, Robert George Séquestration chimique de co2, de nox et de so2

Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4406867A (en) * 1980-04-17 1983-09-27 Union Carbide Corporation Process for the purification of non-reacting gases
US20120171095A1 (en) * 2008-12-24 2012-07-05 General Electric Company Liquid carbon dioxide absorbents, methods of using the same, and related systems

Patent Citations (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4406867A (en) * 1980-04-17 1983-09-27 Union Carbide Corporation Process for the purification of non-reacting gases
US20120171095A1 (en) * 2008-12-24 2012-07-05 General Electric Company Liquid carbon dioxide absorbents, methods of using the same, and related systems

Non-Patent Citations (2)

* Cited by examiner, † Cited by third party
Title
MAHMOUDKHANI M ET AL: "Low energy packed tower and caustic recovery for direct capture of CO2 from air", ENERGY PROCEDIA, ELSEVIER, NL, vol. 1, no. 1, 1 February 2009 (2009-02-01), pages 1535 - 1542, XP026472048, ISSN: 1876-6102, [retrieved on 20090201], DOI: 10.1016/J.EGYPRO.2009.01.201 *
WEISS, S. ET AL: "Verfahrenstechnische Berechnungsmethoden", vol. 2, 1986, VCH VERLAGSGESELLSCHAFT MBH, D-6940 Weinheim, article WEISS, S. ET AL: "Absorption", pages: 194 - 200, XP002768102 *

Cited By (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP3914376A4 (fr) * 2019-01-28 2023-02-15 Richardson, Robert George Séquestration chimique de co2, de nox et de so2

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