US20140086811A1 - Carbon dioxide recovering apparatus and method for operating the same - Google Patents

Carbon dioxide recovering apparatus and method for operating the same Download PDF

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Publication number
US20140086811A1
US20140086811A1 US13/927,848 US201313927848A US2014086811A1 US 20140086811 A1 US20140086811 A1 US 20140086811A1 US 201313927848 A US201313927848 A US 201313927848A US 2014086811 A1 US2014086811 A1 US 2014086811A1
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Prior art keywords
carbon dioxide
rich solution
solution
tower
flow rate
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Abandoned
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US13/927,848
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English (en)
Inventor
Satoshi Saito
Hideo Kitamura
Mitsuru Udatsu
Toshihisa Kiyokuni
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Toshiba Corp
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Toshiba Corp
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Assigned to KABUSHIKI KAISHA TOSHIBA reassignment KABUSHIKI KAISHA TOSHIBA ASSIGNMENT OF ASSIGNORS INTEREST (SEE DOCUMENT FOR DETAILS). Assignors: KITAMURA, HIDEO, KIYOKUNI, TOSHIHISA, SAITO, SATOSHI, UDATSU, MITSURU
Publication of US20140086811A1 publication Critical patent/US20140086811A1/en
Priority to US15/184,727 priority Critical patent/US10173166B2/en
Abandoned legal-status Critical Current

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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
    • B01D53/1425—Regeneration of liquid absorbents
    • 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
    • B01D53/1412—Controlling the absorption process
    • 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
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/20—Organic absorbents
    • B01D2252/204—Amines
    • 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
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2258/00—Sources of waste gases
    • B01D2258/02—Other waste gases
    • B01D2258/0283—Flue gases
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2259/00—Type of treatment
    • B01D2259/65—Employing advanced heat integration, e.g. Pinch technology
    • 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

  • Embodiments described herein relate generally to a carbon dioxide recovering apparatus and a method for operating a carbon dioxide recovering apparatus.
  • a carbon dioxide recovering apparatus one including an absorbing tower causing carbon dioxide contained in the flue gas to be absorbed in an absorbing solution to generate a rich solution, a releasing tower heating the rich solution discharged from the absorbing tower to release and separate carbon dioxide as well as steam and returning a generated lean solution to the absorbing tower, a first heat exchanger allowing the lean solution supplied from the releasing tower to the absorbing tower to pass therethrough, a second heat exchanger allowing carbon dioxide containing steam separated in the releasing tower to pass therethrough, and a flow distributor dividing and supplying the rich solution discharged from the absorbing tower to the first heat exchanger and the second heat exchanger and adapted to cause the rich solution introduced into the first heat exchanger and the second heat exchanger to heat-exchange with the lean solution and the carbon dioxide containing steam, respectively, and to thereafter be supplied to the releasing tower.
  • FIG. 1 is a schematic configuration of a carbon dioxide recovering apparatus according to a first embodiment
  • FIG. 2 is a graph illustrating an example of relationship between a divided flow rate of a rich solution and carbon dioxide recovering energy
  • FIG. 3 is a graph illustrating an example of relationship between the divided flow rate of the rich solution and an amount of condensate water per unit time in a gas-liquid separator
  • FIG. 4 is a schematic configuration of a carbon dioxide recovering apparatus according to a second embodiment
  • FIG. 5 is a graph illustrating relationship between the divided flow rate of the rich solution and the carbon dioxide recovering energy in Example 1;
  • FIG. 6 is a graph illustrating relationship between the divided flow rate of the rich solution and the amount of the condensate water per unit time in the gas-liquid separator in Example 1.
  • a carbon dioxide recovering apparatus includes a flow distributor dividing the first rich solution discharged from an absorbing tower into a second rich solution and a third rich solution, a reheat exchanger heating the second rich solution with a lean solution discharged from a releasing tower as a heat source, a heating unit heating the third rich solution with a carbon dioxide containing steam to be released from the releasing tower as a heat source, a gas-liquid separator separating the carbon dioxide containing steam used to heat the third rich solution into carbon dioxide and condensate water, a measuring unit measuring an amount of the condensate water in the gas-liquid separator, and a controller.
  • the controller controls a flow dividing ratio in the flow distributor based on a change in the amount of the condensate water measured in the measuring unit.
  • FIG. 1 illustrates a schematic configuration of a carbon dioxide recovering apparatus according to a first embodiment.
  • This carbon dioxide recovering apparatus includes an absorbing tower 101 , a reheat exchanger 103 , a gas-liquid separator 132 , coolers 105 and 106 , a releasing tower 102 A, a reboiler 108 , pumps 201 , 202 , and 203 , and a flow distributor 107 .
  • the flue gas containing carbon dioxide 111 introduced into the absorbing tower 101 contacts an absorbing solution that absorbs carbon dioxide, and carbon dioxide is removed.
  • the absorbing solution absorbs carbon dioxide from the flue gas containing carbon dioxide 111 to generate a rich solution 301 .
  • the absorbing tower 101 is a countercurrent gas-liquid contacting unit that brings the flue gas containing carbon dioxide 111 supplied from a lower portion into gas-liquid contact with a lean solution 319 flowing down from an upper portion.
  • the flue gas containing carbon dioxide 111 to be introduced into the absorbing tower 101 is not particularly limited and is combustion exhaust gas or process exhaust gas, for example.
  • the flue gas containing carbon dioxide 111 may be introduced after a cooling treatment as needed.
  • the absorbing solution is not particularly limited as long as it is an alkaline solution and can be an amine aqueous solution such as monoethanolamine (MEA) and diethanolamine (DEA), for example.
  • Decarbonated gas 112 from which carbon dioxide has been removed in the absorbing tower 101 is discharged from an upper portion of the absorbing tower 101 .
  • the rich solution 301 discharged from the absorbing tower 101 is given via the pump 201 to the flow distributor 107 and is divided into rich solutions 302 and 303 .
  • the rich solution 302 heat-exchanges with an after-mentioned lean solution 316 in the reheat exchanger 103 and is thus heated, and a heated rich solution 320 is supplied via the pump 202 to the releasing tower 102 A.
  • the rich solution 303 is provided to a position of the releasing tower 102 A located further on an upper side than a position to which the rich solution 320 is provided, specifically to an after-mentioned heat exchange layer 102 b, as illustrated in FIG. 1 .
  • the releasing tower 102 A has a heat exchange layer 102 a and the heat exchange layer 102 b provided on an upper stage of the heat exchange layer 102 a.
  • the rich solution 303 is supplied to the heat exchange layer 102 b on the upper stage, passes through the heat exchange layer 102 b, and moves downward.
  • the rich solution 320 is supplied between the heat exchange layer 102 a and the heat exchange layer 102 b, passes through the filling layer 102 a on the lower stage, and moves downward.
  • Carbon dioxide containing steam passes through the filling layers 102 a and 102 b upward for heat exchange.
  • the rich solutions 303 and 320 are heated to cause most carbon dioxide as well as steam to be released, separated, and discharged from an upper portion of the releasing tower 102 A as carbon dioxide containing steam 310 , and a high-temperature lean solution 316 from which most carbon dioxide has been removed is discharged from a lower portion of the releasing tower 102 A.
  • the releasing tower 102 A is a countercurrent gas-liquid contacting unit, for example.
  • the reboiler 108 heats a stored solution in the releasing tower 102 A with use of high-temperature steam 140 as an externally-supplied heat. By doing so, the carbon dioxide containing steam moves upward in the releasing tower 102 A.
  • the carbon dioxide containing steam 310 discharged from the releasing tower 102 A is supplied to the cooler 105 , is cooled by a refrigerant 142 such as cold water to be supplied externally, and is discharged to the gas-liquid separator 132 .
  • the carbon dioxide containing steam 310 cooled in the cooler 105 is separated into carbon dioxide 315 and condensate water 314 in the gas-liquid separator 132 , and the carbon dioxide 315 is discharged and recovered.
  • the gas-liquid separator 132 is provided with a water gauge 401 for measurement of water level changes of the condensate water 314 . In other words, an amount of the condensate water in the gas-liquid separator 132 (an amount of the condensate water to be generated per unit time) is measured.
  • the condensate water 314 can be supplied to the releasing tower 102 A.
  • the lean solution 316 discharged from the releasing tower 102 A heat-exchanges with the rich solution 302 in the reheat exchanger 103 .
  • a lean solution 318 after heat exchange in the reheat exchanger 103 is supplied to the cooler 106 and is cooled by a refrigerant 143 such as cold water to be supplied externally.
  • a lean solution 319 cooled in the cooler 106 is supplied to the absorbing tower 101 , absorbs carbon dioxide from the flue gas containing carbon dioxide 111 , and becomes the rich solution 301 . In this manner, in the carbon dioxide recovering apparatus, the absorbing solution circulates between the absorbing tower 101 and the releasing tower 102 A, and carbon dioxide is recovered.
  • the carbon dioxide recovering apparatus also includes a controller 402 that obtains a measurement result of the water gauge 401 and controls divided flow rates (flow dividing ratio) of the rich solutions 302 and 303 in the flow distributor 107 and a heat input amount in the reboiler 108 .
  • FIG. 2 An example of relationship between the divided flow rate of the rich solution 303 and carbon dioxide recovering energy in such a carbon dioxide recovering apparatus is illustrated in FIG. 2 .
  • the divided flow rate of the rich solution 303 when the divided flow rate of the rich solution 303 is raised from zero gradually, the carbon dioxide recovering energy is lowered gradually. This suggests that heat recovery of the rich solution 303 from the carbon dioxide containing steam at the upper portion of the releasing tower 102 A is carried out effectively.
  • the divided flow rate is between predetermined values ⁇ and ⁇ , the carbon dioxide recovering energy keeps a low value.
  • the divided flow rate exceeds the predetermined value ⁇ , the carbon dioxide recovering energy is significantly raised along with the raise of the divided flow rate of the rich solution 303 .
  • FIG. 3 illustrates an example of relationship between the divided flow rate of the rich solution 303 and the amount of the condensate water per unit time in the gas-liquid separator 132 .
  • the amount of the condensate water per unit time is decreased along with the raise of the divided flow rate. The reason for this is that heat recovery of the rich solution 303 from the carbon dioxide containing steam at the upper portion of the releasing tower 102 A is carried out effectively, which causes a decrease in a steam amount to be carried to the gas-liquid separator 132 . It is apparent from FIG. 3 that the amount of the condensate water becomes almost constant when the divided flow rate of the rich solution 303 exceeds the predetermined value ⁇ .
  • a divided flow rate when the amount of the condensate water becomes almost constant that is, when a water level change of the condensate water 314 in the gas-liquid separator 132 to be measured by the water gauge 401 becomes almost constant, after a gradual raise of the divided flow rate of the rich solution 303 from zero, is an optimum divided flow rate in which the carbon dioxide recovering energy is restricted.
  • the divided flow rate of the rich solution 303 can be optimum, heat recovery of the rich solutions 302 and 303 from the lean solution 316 and the carbon dioxide containing steam can be performed effectively, and the carbon dioxide recovering energy can be restricted.
  • FIG. 4 illustrates a schematic configuration of a carbon dioxide recovering apparatus according to a second embodiment.
  • the carbon dioxide recovering apparatus according to the present embodiment differs from the first embodiment illustrated in FIG. 1 in that a carbon dioxide generator 104 and a joining unit 109 are provided, and in that heat exchange between the rich solution 303 and the carbon dioxide containing steam 310 is performed in the carbon dioxide generator 104 .
  • the rich solution 301 discharged from the absorbing tower 101 is divided into the rich solutions 302 and 303 by the flow distributor 107 .
  • the rich solution 302 heat-exchanges with the lean solution 316 in the reheat exchanger 103 and is heated.
  • the rich solution 303 heat-exchanges with the carbon dioxide containing steam 310 in the carbon dioxide generator (heat exchanger) 104 and is heated.
  • Carbon dioxide containing steam 311 that has passed through the carbon dioxide generator 104 is supplied to the cooler 105 .
  • the rich solution 320 heated in the reheat exchanger 103 and a rich solution 306 heated in the carbon dioxide generator 104 are joined in the joining unit 109 and are supplied to a releasing tower 102 B.
  • the rich solution supplied to the releasing tower 102 B passes through the filling layer 102 a and moves downward. Carbon dioxide containing steam passes through the filling layer 102 a upward for heat exchange with the rich solution.
  • the rich solution is heated to cause most carbon dioxide as well as steam to be released, separated, and discharged from an upper portion of the releasing tower 102 B as the carbon dioxide containing steam 310 , and the high-temperature lean solution 316 from which most carbon dioxide has been removed is discharged from a lower portion of the releasing tower 102 B.
  • an optimum divided flow rate of the rich solution 303 can be determined easily while a water level change of the condensate water 314 in the gas-liquid separator 132 can be monitored. Accordingly, heat recovery of the rich solutions 302 and 303 from the lean solution 316 and the carbon dioxide containing steam can be performed effectively, and carbon dioxide recovering energy can be restricted.
  • an initial value of the divided flow rate of the rich solution 303 may be set to a certain large value, and an optimum divided flow rate may be obtained by decreasing the divided flow rate of the rich solution 303 gradually while confirming that the amount of the condensate water is not increased excessively (that the amount of the condensate water is almost constant).
  • the divided flow rate of the rich solution 303 is lowered gradually until the amount of the condensate water does not fall in a certain range any more.
  • the heat input amount in the reboiler 108 may be controlled while confirming that the amount of the condensate water is not increased excessively (that the amount of the condensate water is almost constant).
  • a mass meter may be used instead of the water gauge 401 , or a flowmeter may be used to measure a flow rate of the condensate water 314 to be returned from the gas-liquid separator 132 to the releasing tower 102 A or 102 B, and the amount of the condensate water may be derived from the measured flow rate.
  • the flue gas containing carbon dioxide 111 with 12% carbon dioxide with a flow rate of 100 Nm 3 /h was supplied to the absorbing tower 101 and was brought into countercurrent contact with an amine absorbing solution in the absorbing tower 101 to prepare the rich solution 301 .
  • the divided flow rate of the rich solution 303 was set to zero, and an entire amount of the rich solution 301 was set as the rich solution 302 .
  • a carbon dioxide recovering ratio at an exit of the absorbing tower 101 was 80%.
  • the heat input amount in the reboiler 108 an amount of steam to be supplied
  • the recovering energy became 4.0 GJ/t-CO 2 .
  • the amount of the condensate water in the gas-liquid separator 132 was 200 L per unit time.
  • FIG. 5 illustrates relationship between the divided flow rate of the rich solution 303 and carbon dioxide recovering energy.
  • FIG. 6 illustrates relationship between the divided flow rate of the rich solution 303 and the amount of the condensate water per unit time in the gas-liquid separator 132 .
  • the flue gas containing carbon dioxide 111 with 12% carbon dioxide with a flow rate of 100 Nm 3 /h was supplied to the absorbing tower 101 and was brought into countercurrent contact with an amine absorbing solution in the absorbing tower 101 to prepare the rich solution 301 .
  • the divided flow rate of the rich solution 303 was set to 30% of the rich solution 301
  • the divided flow rate of the rich solution 302 was set to 70% of the rich solution 301 .
  • the carbon dioxide recovering ratio at the exit of the absorbing tower 101 was 70%, and the amount of the condensate water in the gas-liquid separator 132 was 10 L per unit time. Also, the carbon dioxide recovering energy became 3.8 GJ/t-CO 2 .
  • the carbon dioxide recovering energy was 3.0 GJ/t-CO 2 , and it was confirmed that the carbon dioxide recovering energy was able to be lowered further by 0.8 GJ/t-CO 2 than in a case of setting the divided flow rate of the rich solution 303 to 30% of the rich solution 301 .
  • the flue gas containing carbon dioxide 111 with 12% carbon dioxide with a flow rate of 100 Nm 3 /h was supplied to the absorbing tower 101 and was brought into countercurrent contact with an amine absorbing solution in the absorbing tower 101 to prepare the rich solution 301 .
  • the divided flow rate of the rich solution 303 was set to 30% of the rich solution 301
  • the divided flow rate of the rich solution 302 was set to 70% of the rich solution 301 .
  • Example 3 differs from Example 2 only in that the heat input amount in the reboiler is approximately 5% smaller than that in Example 2.
  • the carbon dioxide recovering ratio at the exit of the absorbing tower 101 was 65%, and the amount of the condensate water in the gas-liquid separator 132 was 15 L per unit time. Also, the carbon dioxide recovering energy became 3.9 GJ/t-CO 2 .
  • the carbon dioxide recovering ratio was raised to 90%.
  • the carbon dioxide recovering energy was 3.0 GJ/t-CO 2 , and it was confirmed that the carbon dioxide recovering energy was able to be lowered by 0.9 GJ/t-CO 2 .
  • the flue gas containing carbon dioxide 111 with 12% carbon dioxide with a flow rate of 100 Nm 3 /h was supplied to the absorbing tower 101 and was brought into countercurrent contact with an amine absorbing solution in the absorbing tower 101 to prepare the rich solution 301 .
  • the divided flow rate of the rich solution 303 was set to zero, and an entire amount of the rich solution 301 was set as the rich solution 302 .
  • a carbon dioxide recovering ratio at an exit of the absorbing tower 101 was 80%.
  • the heat input amount in the reboiler 108 an amount of steam to be supplied
  • the recovering energy became 4.0 GJ/t-CO 2 .
  • the amount of the condensate water in the gas-liquid separator 132 was 200 L per unit time.
  • the flow distributor 107 was controlled by the controller 402 to raise the divided flow rate of the rich solution 303 .
  • the flow rate of the rich solution 303 exceeded 5% of the rich solution 301 , the amount of the condensate water in the gas-liquid separator 132 was decreased to approximately 20 L per unit time and became almost constant.
  • heat recovery of the rich solutions from the lean solution and the carbon dioxide containing steam can be performed effectively, and carbon dioxide recovering energy can be restricted.

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  • Engineering & Computer Science (AREA)
  • Analytical Chemistry (AREA)
  • General Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
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US13/927,848 2012-06-25 2013-06-26 Carbon dioxide recovering apparatus and method for operating the same Abandoned US20140086811A1 (en)

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JP2012141781A JP5767609B2 (ja) 2012-06-25 2012-06-25 二酸化炭素回収装置及びその運転方法

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US9815016B2 (en) 2014-12-05 2017-11-14 Kabushiki Kaisha Toshiba Carbon dioxide capturing system and method of operating the same
US9987586B2 (en) 2014-07-10 2018-06-05 Mitsubishi Heavy Industries, Ltd. CO2 recovery unit and CO2 recovery method
US10213726B2 (en) 2014-07-10 2019-02-26 Mitsubishi Heavy Industries Engineering, Ltd. CO2 recovery unit and CO2 recovery method
EP4023320A4 (fr) * 2019-10-30 2022-09-28 Mitsubishi Heavy Industries Engineering, Ltd. Système de récupération de dioxyde de carbone et méthode de récupération de dioxyde de carbone
US12478913B1 (en) * 2024-09-30 2025-11-25 Schlumberger Technology Corporation Systems and methods of using a cooling system in a carbon capture process

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JP6913604B2 (ja) * 2017-10-27 2021-08-04 株式会社東芝 二酸化炭素分離回収システムおよび二酸化炭素分離回収システムの運転方法
JP6941063B2 (ja) * 2018-01-10 2021-09-29 株式会社東芝 二酸化炭素回収システムおよびその運転方法
CN109092020A (zh) * 2018-10-24 2018-12-28 中石化石油工程技术服务有限公司 适用于相变吸收剂的二氧化碳捕集系统
JP7332404B2 (ja) * 2019-09-12 2023-08-23 株式会社東芝 二酸化炭素回収システムおよびその運転方法
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AU2013206469A1 (en) 2014-01-16
JP5767609B2 (ja) 2015-08-19
EP2679295A2 (fr) 2014-01-01
CN103521051B (zh) 2016-03-30
US20160296880A1 (en) 2016-10-13
CN103521051A (zh) 2014-01-22
EP2679295B1 (fr) 2016-06-22
AU2013206469B2 (en) 2015-07-30
JP2014004525A (ja) 2014-01-16
US10173166B2 (en) 2019-01-08

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