US20080060346A1 - Method for Removing and Recovering Co2 from an Exhaust Gas - Google Patents

Method for Removing and Recovering Co2 from an Exhaust Gas Download PDF

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Publication number
US20080060346A1
US20080060346A1 US11/663,644 US66364405A US2008060346A1 US 20080060346 A1 US20080060346 A1 US 20080060346A1 US 66364405 A US66364405 A US 66364405A US 2008060346 A1 US2008060346 A1 US 2008060346A1
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exhaust gas
power
gas
cooled
main power
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Knut Asen
Dag Eimer
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Norsk Hydro ASA
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Norsk Hydro ASA
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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
    • B01D53/34—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
    • 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
    • B01D53/343—Heat recovery
    • 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
    • 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
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • 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
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
    • 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
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P20/00—Technologies relating to chemical industry
    • Y02P20/10—Process efficiency
    • Y02P20/129—Energy recovery, e.g. by cogeneration, H2recovery or pressure recovery turbines

Definitions

  • the present invention relates to a method for removing and recovering CO 2 from exhaust gas from a gas turbine based electric power and heat generation process by chemical absorption and desorption for deposition of CO 2 as convenient at the location.
  • the concentration or partial pressure of carbon dioxide in the exhaust gas may be raised to higher levels by recirculating exhaust gas as suggested by e.g. Chiesa et al. (paper presented at the International Gas Turbine & Aero engine Congress & Exhibition Sweden—Jun. 2-5, 1998) in a coal based Integrated Gasification and Combined Cycle (IGCC) plant or described by Ronning et al. in Norwegian patent 180520.
  • IGCC coal based Integrated Gasification and Combined Cycle
  • CO 2 can be removed from exhaust gas by means of several separation processes, e.g. chemically active absorption processes, physical absorption processes, adsorption by molecular sieves, membrane separation, and cryogenic techniques.
  • separation processes e.g. chemically active absorption processes, physical absorption processes, adsorption by molecular sieves, membrane separation, and cryogenic techniques.
  • An improved process for compression of exhaust gas is known from European patent 1159056.
  • the patent describes a method for removing and recovering CO 2 from exhaust gas from a power and/or heat generation process (a main power process) by chemical absorption and desorption respectively.
  • the exhaust gas from a first gas turbine is cooled and recompressed to an elevated pressure in a compressor in a secondary power plant before entering a chemical absorption process at elevated pressure.
  • the CO 2 -depleted exhaust gas emerging from the absorber is reheated and further expanded in an expander in said secondary power plant.
  • the international patent application WO04/026445 describes a method where exhaust gas from a first gas turbine cycle is compressed before absorption of CO 2 .
  • the compression is performed in preferably several steps with intercooling before the oxygen containing exhaust gas is cooled and fed to a CO 2 absorption process.
  • the two stage power plant concept suggested in WO04/026445 will reduce the steam production in the first power plant and thus the electric power generation since part of the cooled CO 2 depleted exhaust gas is heat exchanged with exhaust gas in the first power plant. Due to the limited temperature of the exhaust gas from the first power cycle (normally below 600° C.) the gas entering the gas turbine expander in the second power plant will have a temperature that is significantly lower than the temperature in the combustion chamber in said second power cycle. Also the suggested addition of water to the CO 2 depleted exhaust gas may reduce the inlet temperature to the turbine in the second power cycle. This will reduce the efficiency of the total process as well as reduce the total power production.
  • the concentration of carbon dioxide in the exhaust gas may be raised to higher levels by recirculating exhaust gas suggested by e.g. Chiesa et al. (paper presented at the International Gas Turbine & Aeroengine Congress & Exhibition Sweden—Jun. 2-5, 1998) in a coal based Integrated Gasification and Combined Cycle (IGCC) plant or described by Running et al. in Norwegian patent 180520.
  • This also implies significant changes in the power generation process due to the recycle of up to 50% of the exhaust gas.
  • the alternative solution as described in the European patent 1159056 and WO04/026445 also implies significant changes in the power generation process due to significant integration between the two power generation processes connected in series.
  • the suggested absorption of CO 2 at high pressure (as described e.g. in WO04/026445) before the exhaust gas is depressurised in the turbine expander will significantly increase the pressure drop between the compressor and the turbine expander and thus reduce the thermal efficiency of the secondary electric power and heat generation process.
  • the high pressure CO 2 depleted exhaust gas generated in the secondary power process plant is reheated in a high temperature fired heater located in the main or first power process plant and further transported back to the secondary power process plant where the heated gas enters a turbine.
  • a high turbine inlet temperature is advantageous since this will increase the thermal efficiency of the power process plant. This applies to all gas turbine cycles according to the principle of the Brayton cycle. Reheating of the CO 2 depleted exhaust gas in the first or main power process plant will increase the fuel consumption without increasing the air flow through the gas turbine and thus increase the concentration of CO 2 in exhaust gas from the first or main power process plant. The concentration of CO 2 is not further increased in the secondary power process plant.
  • amines than MEA i.e. tertiary amines like MDEA (methyidiethanolamine) can be used if the exhaust gas is compressed to an elevated pressure. MDEA need less energy in the desorption process than MEA.
  • a more efficient absorption medium e.g. aqueous hindered amine solution as disclosed in U.S. Pat. No. 5,603,908, the difference between the energy consumption of CO 2 captured at close to atmospheric pressure and the energy consumption of CO 2 captured at elevated pressure is reduced.
  • a more efficient secondary power process plant can be developed, adsorption of CO 2 at close to ambient pressure becomes more attractive.
  • the main objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 in exhaust gas from a main gas turbine based electric power and heat generation process in a way that implies increased thermal efficiency and reduced investment and operating costs per kW installed capacity.
  • Another objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 from exhaust gas from a main gas turbine based electric power and heat generation process in a way that will not reduce utilisation of the installed steam turbines.
  • a further objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 from exhaust gas from a main gas turbine based electric power and heat generation process in a way that reduces the shut down period of the main electric power and heat generation process when a chemical absorption and desorption process or any other process capable of separating CO 2 from exhaust gas is constructed and connected to the said main power process.
  • Still another objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 from exhaust gas from a main gas turbine based electric power and heat generating process in a way that will not require mechanical modifications of installed equipments in the main power and heat generation process.
  • Still another objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 from exhaust gas from a main gas turbine based electric power and heat generation process in a way that will reduce the thermal and electric power losses in any secondary electric power and heat generation process.
  • Still a further objective of the present invention was to arrive at an improved method for capture and recovering of CO 2 from exhaust gas from a main gas turbine based electric power and heat generating process in a way that implies increased concentration of CO 2 in the exhaust gas without recycling of exhaust gas.
  • a secondary electric power and heat generation process is connected to a first main electric power and heat generation process and where a CO 2 absorption and desorption process or any other process capable of separating CO 2 from exhaust gas (i.e. the CO 2 separation process) is connected to the secondary power and heat generation process and where 5-100% of the exhaust gas from the main power and heat generation process is fed to the secondary heat and power generation process.
  • the secondary process is designed to supply a sufficient amount of heat and power required to operate the CO 2 separating process. Any additional production of electric power and heat may be exported to the grid.
  • the secondary electric power and heat generation process including a CO 2 separation process can then be connected to the main process without interfering with or reducing the capacity of the main process.
  • the secondary power process including the CO 2 separating process has no connection to the main process except for the exhaust gas duct from said main process the time needed to connect the two power and heat generation processes is reduced. This will reduce the required shut down period. This has a significant cost saving effect since the loss in production of electric power from the main power process is reduced to a minimum due to the reduced shut down time. It also allows building of a conventional gas turbine based power and heat generation plant that may be operated for several years before the secondary gas turbine based electric power and heat generation process plant including the CO 2 separation process is constructed and connected to the first power and heat generation process. This will have significant economic benefits during the construction period of the secondary power and heat generation process plant.
  • the exhaust gas from the main gas turbine power plant is used as oxidant in a secondary gas turbine combustion chamber installed in the secondary power process and before the exhaust gas is entering the CO 2 separation process.
  • concentration of CO 2 in the exhaust gas will be raised from 3-5% in the first power plant to 7-9% in the secondary power plant.
  • the CO 2 depleted gas is not heat exchanged with the exhaust gas stream in the main electric power and heat generation process. This will eliminate the problems related to the integration of the two electric power and heat generation processes.
  • the compressed exhaust gas from the main power process is fed directly to a combustion chamber where a carbon containing fuel is combusted and the resulting hot exhaust then enters a turbine where the pressure is reduced to close to ambient pressure before separation of CO 2 .
  • the combined secondary power and heat generation process and CO 2 separation process is self-sufficient with regard to both thermal heat and electric power or do not interfere with or reduce the capacity of the main power and heat generation process.
  • the inventors thus found a method for capture and recovering of CO 2 in exhaust gas from a gas turbine based power and heat generation process (a main power process) by absorption and desorption respectively or by any other process capable of separating CO 2 from exhaust gas, where the exhaust gas from the main power process is cooled to below 50° C. before being fed to a secondary gas turbine based power and heat generation process (a secondary power process) and where the exhaust gas is compressed adiabatically to elevated pressure (preferably above 5 bar) and further used as oxidant in a secondary gas turbine combustion chamber where the temperature is increased to above 850° C. and preferably above 1200° C.
  • the resulting hot exhaust gas is further fed to a turbine connected to an electric power generator where the exhaust gas is depressurised to close to ambient pressure.
  • the depressurised exhaust gas further enters a heat recovery section where the exhaust gas is cooled to preferably below 100° C.
  • Recovered thermal heat is partly used in the CO 2 separation process.
  • Recovered heat may be further partly used to generate steam that may be used to generate power in steam turbines.
  • Further recovered heat may be partly used to heat a heating medium, e.g. water containing glycol.
  • both plants may be run independently of each other. If the secondary power process including the CO 2 separation process is shut down for e.g. maintenance work, the first plant may still operate on design capacity. If the main power process is shut down for a period of time, the secondary plant including the CO 2 separation process may be operated close to design capacity.
  • the main power plant may be constructed and operated for several years without CO 2 capture.
  • the secondary power plant including a CO 2 separation process may be constructed and connected to the main power plant without modifications of the main power process since all necessary utilities will be supplied from the secondary power process.
  • FIG. 1 shows a post combustion process according to the present invention including two Gas Turbine Combined Cycle (CCGT) plants in series with only one CO 2 scrubbing plant.
  • CCGT Gas Turbine Combined Cycle
  • FIG. 1 A first figure.
  • Air 1 enters compressor 30 and is compressed to between 10 and 40 bar before being fed to a combustor 31 where a fuel 3 is combusted.
  • the hot combusted gas 4 then enters turbine 32 .
  • This unit may drive a compressor or electrical generator.
  • Exhaust gas 5 at low pressure enters a waste gas heat recovery unit 33 where steam 25 is generated by evaporating boiler feed water 24 .
  • Partly cooled exhaust gas 6 at about 100° C. is further cooled in a cooling tower 34 by means of circulating cooling water 28 . Used water 29 is disposed of or partly recycled.
  • Application of a cooling tower is only shown as an example and the present invention is not restricted to the use of this unit.
  • the exhaust gas 6 may also be cooled in a water-cooled heat exchanger or by any other means.
  • Condensed water 8 is separated in unit 41 and fresh air 10 is optionally added in mixer 42 .
  • Oxygen containing gas stream 11 enters compressor 35 and is compressed to between 5 and 40 bar before being fed to a combustor 36 where a fuel 13 is combusted.
  • the hot combusted gas 14 then enters turbine 37 .
  • This unit may drive a compressor or electrical generator.
  • Exhaust gas 15 at close to ambient pressure enters a waste gas heat recovery unit 38 where steam 27 is generated by evaporating boiler feed water 26 .
  • Partly cooled exhaust gas 16 is optionally further cooled in a cooling tower 39 by means of circulation cooling water 17 . Used water 18 is disposed of or partly recycled.
  • Application of a cooling tower is only shown as an example and the present invention is not restricted to the use of this unit.
  • the exhaust gas 16 may also be cooled in a water-cooled heat exchanger or by any other means.
  • Any condensed water 20 is separated in unit 43 .
  • the CO 2 containing exhaust gas stream 21 enters a CO 2 separation process (i.e. an CO 2 absorption and desorption process) 40 where preferably more than 80% of the CO 2 content is removed.
  • Captured CO 2 22 may be compressed and dried in preparation to be deposited in a geological formation.
  • CO 2 depleted exhaust gas is vented off 23 . Heat recovered from the exhaust gas may be partly used in unit 40 .
  • the main principle of the concept as shown in FIG. 1 is that exhaust gas from the first CCGT plant is cooled to below 100° C. before being fed to a second CCGT plant.
  • the exhaust gas from this second CCGT plant is cooled to preferably below 100° C. and fed to a CO 2 absorption and desorption plant.
  • the concept has several advantages compared to the traditional post combustion concepts:
  • Table 1 shows composition of the exhaust gas stream 9 and the exhaust gas stream 21 .
  • the exhaust gas stream 9 (77987 kmol/hr) containing 4.3% CO 2 is treated in a CO 2 absorption and desorption process.
  • the output from this electric power plant inclusive CO 2 capture will be about 330 MW if the fuel to electric power efficiency is 48.5% (measured as low heating value) and if a conventional absorption medium is applied.
  • the output will be about 395 MW without CO 2 separation.
  • exhaust gas stream 9 instead is fed to a secondary gas turbine combined cycle power plant of about the same size as the first one, the exhaust gas stream 21 (after condensation and removal of water) from the secondary process will contain 8.8% CO 2 .
  • the amount of gas is reduced to 75172 kmol/hr.
  • concentration of CO 2 in the gas stream entering the CO 2 separation plant is increased from 4.3% to 8.8% while the amount of gas to be treated is slightly reduced.
  • the power output from this novel two-stage power process will be about 790 MW exclusive CO 2 separation. According to Mimura et al. (“Development and application of flue gas carbon dioxide recovery technology”. Paper presented at the Green House Gas Technology conference in Cairns, Australia, 13-16 Aug.
  • the increase in the concentration of CO 2 in the exhaust gas from about 4.3% CO 2 to 8.8% CO 2 will reduce the energy requirement with about 10%.
  • the total power output thus will be about 675 MW while the power output from two separate power plants including an absorption and desorption process will be about 360 MW. In this case the total electric power plant efficiency is increased from 48.5% to about 49.5%.
  • Another advantage is that the size of the absorption process is reduced compared to the alternative with two power plants in parallel. This is because the amount of gas to be treated is reduced with more than 50%.
US11/663,644 2004-10-20 2005-10-12 Method for Removing and Recovering Co2 from an Exhaust Gas Abandoned US20080060346A1 (en)

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
NO20044456A NO20044456L (no) 2004-10-20 2004-10-20 Fremgangsmate for fjerning og gjenvinning av C02 fra eksosgass
NO20044456 2004-10-20
PCT/NO2005/000379 WO2006043820A1 (en) 2004-10-20 2005-10-12 Method for removing and recovering co2 from an exhaust gas

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US (1) US20080060346A1 (ja)
EP (1) EP1827656B1 (ja)
JP (2) JP2008517216A (ja)
AT (1) ATE507896T1 (ja)
CA (1) CA2581271A1 (ja)
DE (1) DE602005027893D1 (ja)
DK (1) DK1827656T3 (ja)
NO (1) NO20044456L (ja)
WO (1) WO2006043820A1 (ja)

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CA2581271A1 (en) 2006-04-27
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DE602005027893D1 (de) 2011-06-16
JP2012062897A (ja) 2012-03-29
JP2008517216A (ja) 2008-05-22
EP1827656A4 (en) 2010-02-17
NO20044456L (no) 2005-03-03
ATE507896T1 (de) 2011-05-15
WO2006043820A1 (en) 2006-04-27
DK1827656T3 (da) 2011-08-15

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