CA2697235A1 - Process for the separation of pressurised carbon dioxide from steam - Google Patents
Process for the separation of pressurised carbon dioxide from steam Download PDFInfo
- Publication number
- CA2697235A1 CA2697235A1 CA2697235A CA2697235A CA2697235A1 CA 2697235 A1 CA2697235 A1 CA 2697235A1 CA 2697235 A CA2697235 A CA 2697235A CA 2697235 A CA2697235 A CA 2697235A CA 2697235 A1 CA2697235 A1 CA 2697235A1
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- Prior art keywords
- steam
- carbon dioxide
- stream
- cooling
- cooled
- 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.)
- Abandoned
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 106
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 53
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 50
- 238000000926 separation method Methods 0.000 title claims abstract description 12
- 238000000034 method Methods 0.000 title claims description 16
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 25
- 238000001816 cooling Methods 0.000 claims abstract description 16
- 238000009833 condensation Methods 0.000 claims description 17
- 230000005494 condensation Effects 0.000 claims description 17
- 238000002485 combustion reaction Methods 0.000 claims description 13
- 238000010248 power generation Methods 0.000 claims description 7
- 239000002826 coolant Substances 0.000 claims description 6
- NINIDFKCEFEMDL-UHFFFAOYSA-N Sulfur Chemical compound [S] NINIDFKCEFEMDL-UHFFFAOYSA-N 0.000 claims description 4
- 239000005864 Sulphur Substances 0.000 claims description 4
- 239000002803 fossil fuel Substances 0.000 claims description 2
- 230000005611 electricity Effects 0.000 claims 1
- 230000003647 oxidation Effects 0.000 abstract description 5
- 238000007254 oxidation reaction Methods 0.000 abstract description 5
- 239000007789 gas Substances 0.000 description 13
- QVGXLLKOCUKJST-UHFFFAOYSA-N atomic oxygen Chemical compound [O] QVGXLLKOCUKJST-UHFFFAOYSA-N 0.000 description 9
- 239000001301 oxygen Substances 0.000 description 9
- 229910052760 oxygen Inorganic materials 0.000 description 9
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 8
- 239000000203 mixture Substances 0.000 description 7
- 230000006835 compression Effects 0.000 description 6
- 238000007906 compression Methods 0.000 description 6
- XKRFYHLGVUSROY-UHFFFAOYSA-N Argon Chemical compound [Ar] XKRFYHLGVUSROY-UHFFFAOYSA-N 0.000 description 4
- 239000006227 byproduct Substances 0.000 description 4
- 239000000356 contaminant Substances 0.000 description 4
- 229910052757 nitrogen Inorganic materials 0.000 description 4
- 238000012856 packing Methods 0.000 description 4
- 239000002253 acid Substances 0.000 description 3
- 239000000047 product Substances 0.000 description 3
- RAHZWNYVWXNFOC-UHFFFAOYSA-N Sulphur dioxide Chemical compound O=S=O RAHZWNYVWXNFOC-UHFFFAOYSA-N 0.000 description 2
- 229910052786 argon Inorganic materials 0.000 description 2
- 239000012535 impurity Substances 0.000 description 2
- 239000013618 particulate matter Substances 0.000 description 2
- 238000011084 recovery Methods 0.000 description 2
- 239000003245 coal Substances 0.000 description 1
- 239000000567 combustion gas Substances 0.000 description 1
- 239000012141 concentrate Substances 0.000 description 1
- 239000003085 diluting agent Substances 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000002737 fuel gas Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000002184 metal Substances 0.000 description 1
- 238000002156 mixing Methods 0.000 description 1
- 229920006395 saturated elastomer Polymers 0.000 description 1
- 238000005201 scrubbing Methods 0.000 description 1
- 239000002904 solvent Substances 0.000 description 1
- 238000004326 stimulated echo acquisition mode for imaging Methods 0.000 description 1
- 239000000126 substance Substances 0.000 description 1
- XTQHKBHJIVJGKJ-UHFFFAOYSA-N sulfur monoxide Chemical class S=O XTQHKBHJIVJGKJ-UHFFFAOYSA-N 0.000 description 1
- 239000004291 sulphur dioxide Substances 0.000 description 1
- 235000010269 sulphur dioxide Nutrition 0.000 description 1
- 238000005406 washing Methods 0.000 description 1
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
- B01D53/002—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 condensation
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K17/00—Using steam or condensate extracted or exhausted from steam engine plant
- F01K17/06—Returning energy of steam, in exchanged form, to process, e.g. use of exhaust steam for drying solid fuel or plant
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K21/00—Steam engine plants not otherwise provided for
- F01K21/04—Steam engine plants not otherwise provided for using mixtures of steam and gas; Plants generating or heating steam by bringing water or steam into direct contact with hot gas
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F01—MACHINES OR ENGINES IN GENERAL; ENGINE PLANTS IN GENERAL; STEAM ENGINES
- F01K—STEAM ENGINE PLANTS; STEAM ACCUMULATORS; ENGINE PLANTS NOT OTHERWISE PROVIDED FOR; ENGINES USING SPECIAL WORKING FLUIDS OR CYCLES
- F01K7/00—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating
- F01K7/16—Steam engine plants characterised by the use of specific types of engine; Plants or engines characterised by their use of special steam systems, cycles or processes; Control means specially adapted for such systems, cycles or processes; Use of withdrawn or exhaust steam for feed-water heating the engines being only of turbine type
-
- 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
- B01D2257/302—Sulfur oxides
-
- 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
- B01D2257/502—Carbon monoxide
Landscapes
- Engineering & Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Combustion & Propulsion (AREA)
- Mechanical Engineering (AREA)
- General Engineering & Computer Science (AREA)
- Analytical Chemistry (AREA)
- General Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Chemical Kinetics & Catalysis (AREA)
- Carbon And Carbon Compounds (AREA)
- Treating Waste Gases (AREA)
Abstract
This invention relates to the separation of carbon dioxide gas from a substantially particulate free pressurised gaseous stream of steam and carbon dioxide, such as that generated by the oxidation of a fossil feedstock used in the generation of electric power. Here the stream is cooled by direct water cooling at a pressure of at least 1 bar absolute to condense out essentially all of the steam therein and leave a carbon dioxide stream at pressure for capture or other use.
Description
PROCESS FOR THE SEPARATION OF PRESSURISED CARBON DIOXIDE
FROM STEAM
This invention relates to the separation of carbon dioxide gas from a pressurised stream of steam and carbon dioxide. Such a stream is typically produced by the combustion of a fuel gas with oxygen at elevated pressures and is used to generate shaft power, which may be used for the generation of electric power. Such pressurised stream of steam and carbon dioxide can contain particulate matter depending on the method of combustion. Such particulate matter is preferentially substantially removed using well known means such as filtration, by cyclone separation or, preferentially, liquid washing.
Often this carbon dioxide is separated from the steam.
In the present invention the separation step is carried out at elevated pressure. By this means the separated carbon dioxide remains at elevated pressure and the sensible heat in the stream is recovered and used in the raising of steam for the further generation of shaft power which may be used for the generation of further electric power. This invention has particular utility in the case where the combustion gases are fed to a hot expander to generate shaft-power.
To obviate confusion, there follow definitions of the terms "direct cooling" and "indirect cooling" as used in this document.
FROM STEAM
This invention relates to the separation of carbon dioxide gas from a pressurised stream of steam and carbon dioxide. Such a stream is typically produced by the combustion of a fuel gas with oxygen at elevated pressures and is used to generate shaft power, which may be used for the generation of electric power. Such pressurised stream of steam and carbon dioxide can contain particulate matter depending on the method of combustion. Such particulate matter is preferentially substantially removed using well known means such as filtration, by cyclone separation or, preferentially, liquid washing.
Often this carbon dioxide is separated from the steam.
In the present invention the separation step is carried out at elevated pressure. By this means the separated carbon dioxide remains at elevated pressure and the sensible heat in the stream is recovered and used in the raising of steam for the further generation of shaft power which may be used for the generation of further electric power. This invention has particular utility in the case where the combustion gases are fed to a hot expander to generate shaft-power.
To obviate confusion, there follow definitions of the terms "direct cooling" and "indirect cooling" as used in this document.
Indirect cooling means the transfer of heat from a stream at one temperature to a lower temperature stream without any mixing of the stream, such as through the medium of a metal wall separating the two streams in a heat exchanger.
Direct cooling means the transfer of heat from a stream at one temperature to a lower temperature stream through direct contact of the two streams in a vessel.
Traditional power generation from fossil feedstocks, such as coal, consists of the release of the fossil feedstock chemical energy in the form of heat through its oxidation or combustion with oxygen. The released heat is used to raise steam which may be expanded in an expander or steam turbine to generate shaft power. Because carbon dioxide is the principal non-condensable by-product of the oxidation of a fossil feedstock, this results in a major contribution of carbon dioxide emissions normally released to the atmosphere. Traditional power generation also uses atmospheric air as the normal source of oxygen for the oxidation or combustion process. This means that the very high concentration of nitrogen associated with oxygen in atmospheric air will be mixed with the by-product carbon dioxide resulting from the oxidation or combustion process.
It may be required to remove or "capture" the COa by-product of such a power generation process in order to place it in a suitable storage system to obviate any undesirable effects of its release into the atmosphere.
Direct cooling means the transfer of heat from a stream at one temperature to a lower temperature stream through direct contact of the two streams in a vessel.
Traditional power generation from fossil feedstocks, such as coal, consists of the release of the fossil feedstock chemical energy in the form of heat through its oxidation or combustion with oxygen. The released heat is used to raise steam which may be expanded in an expander or steam turbine to generate shaft power. Because carbon dioxide is the principal non-condensable by-product of the oxidation of a fossil feedstock, this results in a major contribution of carbon dioxide emissions normally released to the atmosphere. Traditional power generation also uses atmospheric air as the normal source of oxygen for the oxidation or combustion process. This means that the very high concentration of nitrogen associated with oxygen in atmospheric air will be mixed with the by-product carbon dioxide resulting from the oxidation or combustion process.
It may be required to remove or "capture" the COa by-product of such a power generation process in order to place it in a suitable storage system to obviate any undesirable effects of its release into the atmosphere.
In such a case, the use of atmospheric air for combustion and the resulting mixture of by-product gases makes the selective capture of carbon dioxide cumbersome.
It is well known that if high purity oxygen, that is oxygen produced by a cryogenic air separation unit such as that disclosed in US Patent No. 3,134,228, were substituted for atmospheric air, then the products of combustion will consist almost entirely of water vapour and carbon dioxide. This creates the possibility to condense out the water leaving the non-condensable carbon dioxide available for compression and transport, preferably by pipeline, to a storage site. Air separation units typically provide oxygen of from 95% up to 99.5% by volume purity, the contaminants consisting mainly of nitrogen together with a small proportion of argon. Here the higher the purity of the oxygen, the lower the proportion of these contaminants in the captured carbon dioxide.
Such a known process may be carried out either at atmospheric pressure or at elevated pressure.
For the atmospheric case, the heats of combustion and water condensation are recovered by indirect heat exchange to raise steam to be used to generate shaft power and to substantially condense by indirectly cooling with typically water or air all the steam, thus leaving the residual carbon dioxide to be compressed from sub-atmospheric pressure.
It is well known that if high purity oxygen, that is oxygen produced by a cryogenic air separation unit such as that disclosed in US Patent No. 3,134,228, were substituted for atmospheric air, then the products of combustion will consist almost entirely of water vapour and carbon dioxide. This creates the possibility to condense out the water leaving the non-condensable carbon dioxide available for compression and transport, preferably by pipeline, to a storage site. Air separation units typically provide oxygen of from 95% up to 99.5% by volume purity, the contaminants consisting mainly of nitrogen together with a small proportion of argon. Here the higher the purity of the oxygen, the lower the proportion of these contaminants in the captured carbon dioxide.
Such a known process may be carried out either at atmospheric pressure or at elevated pressure.
For the atmospheric case, the heats of combustion and water condensation are recovered by indirect heat exchange to raise steam to be used to generate shaft power and to substantially condense by indirectly cooling with typically water or air all the steam, thus leaving the residual carbon dioxide to be compressed from sub-atmospheric pressure.
The elevated pressure alternative conventionally recovers the heats of combustion and water condensation by a combination of hot expansion of the products of combustion to generate shaft power plus indirect heat exchange to raise steam to be used to generate shaft power and to substantially condense by indirectly cooling with typically water or air all the steam, thus leaving the residual carbon dioxide to be compressed from sub-atmospheric pressure.
The hot expander device used to expand the products of combustion to generate power may require cooling for the mechanical parts of the expander. Hitherto such cooling has been provided either by steam or else by recycled carbon dioxide. In both cases the cooling medium must be sufficiently dry to avoid any condensation of water vapour in the expander, particularly if any acid gases are present.
In order to maximise heat recovery in both the atmospheric and elevated pressure cases, it is standard practice for the final condensation pressure for the steam and carbon dioxide to be taken as low as possible, and in any case at least below 1 bar absolute, through indirect heat exchange which means that the compression of the carbon dioxide from this low pressure is expensive in both energy and capital cost. The standard steam condenser is two phase as the steam is mixed with a high proportion of non-condensable carbon dioxide. Such two phase condensers are used in the recovery of heat from geologically sourced natural steam and are known as "geothermal condensers". They are characterised by being larger and therefore more expensive than conventional steam condensers of the same heat load because of the higher volume required to permit effective separation of the steam condensate from the non-condensable gas 5 content.
Furthermore, any other water soluble non-condensing contaminants contained in the carbon dioxide, resulting from impurities in the fossil fuel, and particularly any oxides of sulphur, will be partially dissolved in the steam condensate.
When recycled carbon dioxide is used as a cooling medium for the hot expander, this is generally taken off after condensation which means that although the gas is dry it has to be compressed up to expander pressure from a relatively low pressure starting point.
In this invention, the condensation of the steam content of the steam/carbon dioxide mixture is effected at an elevated pressure above 1 bar absolute, and preferably between 4 and 15 bars absolute, by heat exchange with a stream of water from which the heat content of the steam is recovered for use in the raising of steam. By using this pressurised condensation system a side stream of the steam/carbon dioxide mixture can be taken off - still at an elevated pressure and before condensation - to act as a cooling medium for the hot expander without the risk of, particularly, acid gas condensation and with a much reduced requirement for compression.
Preferably direct cooling using a counter-current stream of circulating water is used. This cooling is effected sufficiently to condense out essentially all, i.e. as much as is practically possible, viz. usually at least 90% by volume, of the steam present in the stream. This leaves a separated carbon dioxide stream still at the condensing pressure of at least 1 bar absolute. Any non-water soluble non-condensing contaminants such as nitrogen can be left in the carbon dioxide stream as a diluent or separated out if desired.
The advantages of this invention are:
1. The carbon dioxide and other non-condensing gases are available at a pressure of at least 1 bar absolute and preferably between 4 and 15 bar absolute.
This means that the compression energy required to compress the carbon dioxide and other non-condensing gases to a pressure sufficient for their transportation to a suitable storage site is significantly reduced below that required if the carbon dioxide and other non-condensing gases were made available for compression only at pressures at or below 1 bar absolute.
2. Some of the steam/carbon dioxide mixture can be extracted before cooling down to the water condensation point, compressed, and recycled for use as a cooling medium for the hot expander used to generate power, as an alternative to steam or recycled carbon dioxide.
3. The carbon dioxide is separated from the steam/carbon dioxide stream in a simple and non-expensive system.
The hot expander device used to expand the products of combustion to generate power may require cooling for the mechanical parts of the expander. Hitherto such cooling has been provided either by steam or else by recycled carbon dioxide. In both cases the cooling medium must be sufficiently dry to avoid any condensation of water vapour in the expander, particularly if any acid gases are present.
In order to maximise heat recovery in both the atmospheric and elevated pressure cases, it is standard practice for the final condensation pressure for the steam and carbon dioxide to be taken as low as possible, and in any case at least below 1 bar absolute, through indirect heat exchange which means that the compression of the carbon dioxide from this low pressure is expensive in both energy and capital cost. The standard steam condenser is two phase as the steam is mixed with a high proportion of non-condensable carbon dioxide. Such two phase condensers are used in the recovery of heat from geologically sourced natural steam and are known as "geothermal condensers". They are characterised by being larger and therefore more expensive than conventional steam condensers of the same heat load because of the higher volume required to permit effective separation of the steam condensate from the non-condensable gas 5 content.
Furthermore, any other water soluble non-condensing contaminants contained in the carbon dioxide, resulting from impurities in the fossil fuel, and particularly any oxides of sulphur, will be partially dissolved in the steam condensate.
When recycled carbon dioxide is used as a cooling medium for the hot expander, this is generally taken off after condensation which means that although the gas is dry it has to be compressed up to expander pressure from a relatively low pressure starting point.
In this invention, the condensation of the steam content of the steam/carbon dioxide mixture is effected at an elevated pressure above 1 bar absolute, and preferably between 4 and 15 bars absolute, by heat exchange with a stream of water from which the heat content of the steam is recovered for use in the raising of steam. By using this pressurised condensation system a side stream of the steam/carbon dioxide mixture can be taken off - still at an elevated pressure and before condensation - to act as a cooling medium for the hot expander without the risk of, particularly, acid gas condensation and with a much reduced requirement for compression.
Preferably direct cooling using a counter-current stream of circulating water is used. This cooling is effected sufficiently to condense out essentially all, i.e. as much as is practically possible, viz. usually at least 90% by volume, of the steam present in the stream. This leaves a separated carbon dioxide stream still at the condensing pressure of at least 1 bar absolute. Any non-water soluble non-condensing contaminants such as nitrogen can be left in the carbon dioxide stream as a diluent or separated out if desired.
The advantages of this invention are:
1. The carbon dioxide and other non-condensing gases are available at a pressure of at least 1 bar absolute and preferably between 4 and 15 bar absolute.
This means that the compression energy required to compress the carbon dioxide and other non-condensing gases to a pressure sufficient for their transportation to a suitable storage site is significantly reduced below that required if the carbon dioxide and other non-condensing gases were made available for compression only at pressures at or below 1 bar absolute.
2. Some of the steam/carbon dioxide mixture can be extracted before cooling down to the water condensation point, compressed, and recycled for use as a cooling medium for the hot expander used to generate power, as an alternative to steam or recycled carbon dioxide.
3. The carbon dioxide is separated from the steam/carbon dioxide stream in a simple and non-expensive system.
4. The heat of condensation of the steam is recovered at a higher temperature and at a relatively low cost compared to the case when two phase condensers operating at pressures at or below 1 bar absolute are used.
5. Any superheat content, that is, the heat content above condensation of the steam and carbon dioxide stream can be recovered by indirect heat exchange down to the saturation/condensation point.
6. Condensation of the stream above 1 bar absolute means that the condensation and separation occurs at a higher temperature than it would be at or below 1 bar absolute. This means that a much higher proportion of sulphur oxides in the steam/carbon dioxide stream resulting from the combustion of sulphur impurities in the fossil feedstock will be present in the non-condensing part of the stream compressed for transportation to storage. If desired, this can be removed from the compressed non-condensing stream using means of scrubbing with a suitable solvent.
The present invention will now be described by way of examples with reference to the accompanying drawing of a schematic flow sheet. This flow sheet shows the carbon dioxide/steam separation section of a power generation process in which a fossil feedstock is oxidised to form a pressurised stream of steam and carbon dioxide which is used to produce electric power via shaft power.
5. Any superheat content, that is, the heat content above condensation of the steam and carbon dioxide stream can be recovered by indirect heat exchange down to the saturation/condensation point.
6. Condensation of the stream above 1 bar absolute means that the condensation and separation occurs at a higher temperature than it would be at or below 1 bar absolute. This means that a much higher proportion of sulphur oxides in the steam/carbon dioxide stream resulting from the combustion of sulphur impurities in the fossil feedstock will be present in the non-condensing part of the stream compressed for transportation to storage. If desired, this can be removed from the compressed non-condensing stream using means of scrubbing with a suitable solvent.
The present invention will now be described by way of examples with reference to the accompanying drawing of a schematic flow sheet. This flow sheet shows the carbon dioxide/steam separation section of a power generation process in which a fossil feedstock is oxidised to form a pressurised stream of steam and carbon dioxide which is used to produce electric power via shaft power.
In the specific embodiment of the invention shown in Figure 1 103978 kg.mols of a mixture (1) coming from a hot expander (not shown) and containing more than 80% by volume of steam and 20% by volume of non-condensable gases, which gases are more than 90% by volume CO2 plus nitrogen, sulphur dioxide, argon and oxygen, at a pressure of 11 bar absolute and a temperature of 289 C is cooled to its water saturation point of 160 C in heat exchanger (10) and then enters packed vessel (11) below the packing. The steam/gas mixture passes up the packing and is cooled by a 122195 kg.mols counter-flow stream of water (5) which enters vessel (11) at 45 C above the packing. 17302 kg.mols of separated and cooled COa (2) leave vessel (11) at 11 bar absolute pressure at a temperature of 47 C.
Stream (5) is taken from the bottom of vessel (11) at 154 C, fed to pump (12), and then cooled in heat exchanger (13) to 45 C and circulated to the top of vessel (11) to enter above the packing. 79411 kg.mols of surplus water (6) are taken from the water circuit for recycle to the front end of the overall process.
74299 kg.mols of boiler feedwater (4) at 20 C is heated in heat exchangers (13) and (10) to produce saturated steam (3) at 5 bar absolute and 152 C. This steam is then taken off to be used for power generation.
The CO2 stream (2) is scrubbed by water to remove oxides of sulphur in packed vessel (14) leaving the resulting cleaned CO2 stream still at a pressure of greater than 1 bar absolute. Pump. (15) circulates the water stream (7) from the bottom of vessel (14) to the top with a concentrate of dissolved acid gases being taken off as stream (8). The water balance of the circuit is maintained with water stream (9) taken from water stream (6) at 45 C.
Because the mixture (1) is at pressure a side stream can be taken off before heat exchanger (10) and recycled after compression to the hot expander (not shown) from which the stream (1) came to act as a cooling medium for the mechanical parts thereof.
Stream (5) is taken from the bottom of vessel (11) at 154 C, fed to pump (12), and then cooled in heat exchanger (13) to 45 C and circulated to the top of vessel (11) to enter above the packing. 79411 kg.mols of surplus water (6) are taken from the water circuit for recycle to the front end of the overall process.
74299 kg.mols of boiler feedwater (4) at 20 C is heated in heat exchangers (13) and (10) to produce saturated steam (3) at 5 bar absolute and 152 C. This steam is then taken off to be used for power generation.
The CO2 stream (2) is scrubbed by water to remove oxides of sulphur in packed vessel (14) leaving the resulting cleaned CO2 stream still at a pressure of greater than 1 bar absolute. Pump. (15) circulates the water stream (7) from the bottom of vessel (14) to the top with a concentrate of dissolved acid gases being taken off as stream (8). The water balance of the circuit is maintained with water stream (9) taken from water stream (6) at 45 C.
Because the mixture (1) is at pressure a side stream can be taken off before heat exchanger (10) and recycled after compression to the hot expander (not shown) from which the stream (1) came to act as a cooling medium for the mechanical parts thereof.
Claims (8)
1. A process for the separation of carbon dioxide from a substantially particulate free pressurised gaseous stream of steam and carbon dioxide from a power generating expander wherein the stream is cooled at a pressure of at least 1 bar absolute to condense out from the stream essentially all of the steam therein, wherein the separated carbon dioxide leaves the condensation step at a pressure above 1 bar absolute, wherein the cooling is effected by direct cooling using a stream of water from which the heat of the condensed steam and cooled carbon dioxide is recovered.
2. A process as claimed in claim 1 wherein the steam is cooled at a pressure of between 4 and 15 bar absolute.
3. A process as claimed in Claim 1 or Claim 2 wherein a side stream of steam and carbon dioxide is extracted from the main stream of the said pressurised gaseous stream of steam and carbon dioxide before said main stream is cooled down to its water saturation temperature, and wherein said side stream is compressed and recycled for use as a cooling medium in the expander from which the said pressurised gaseous stream of steam and carbon dioxide came.
4. A process as claimed in any one of Claims 1 to 3 wherein the heat recovered from the cooling of the stream of steam and carbon dioxide is used for raising steam for power generation.
5. A process as claimed in any one of Claims 1 to 4 wherein prior to cooling the pressurised gaseous stream of steam and carbon dioxide is pre-cooled to near its water condensation temperature and heat thereby recovered is used in the raising of steam.
6. A process as claimed in Claim 5 wherein the steam raised in used for power generation.
7. A process as claimed in any one of Claims 1 to 6 wherein the separated carbon dioxide is treated to remove oxides of sulphur.
8. A process as claimed in any one of the preceding claims wherein the said pressurised gaseous stream is produced by the combustion of a fossil fuel in a process for generating electricity.
Applications Claiming Priority (5)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB0712929.9 | 2007-07-04 | ||
| GB0712929A GB0712929D0 (en) | 2007-07-04 | 2007-07-04 | Process for the separation of pressurised carbon dioxide from steam |
| GB0800641.3 | 2008-01-15 | ||
| GB0800641A GB0800641D0 (en) | 2008-01-15 | 2008-01-15 | Process for the separation of pressurized carbon dioxide from steam |
| PCT/GB2008/002190 WO2009004307A1 (en) | 2007-07-04 | 2008-06-26 | Process for the separation of pressurised carbon dioxide from steam |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2697235A1 true CA2697235A1 (en) | 2009-01-08 |
Family
ID=39769487
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2697235A Abandoned CA2697235A1 (en) | 2007-07-04 | 2008-06-26 | Process for the separation of pressurised carbon dioxide from steam |
Country Status (4)
| Country | Link |
|---|---|
| EP (1) | EP2175964A1 (en) |
| AU (1) | AU2008272719A1 (en) |
| CA (1) | CA2697235A1 (en) |
| WO (1) | WO2009004307A1 (en) |
Families Citing this family (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US8192530B2 (en) | 2007-12-13 | 2012-06-05 | Alstom Technology Ltd | System and method for regeneration of an absorbent solution |
| US9133407B2 (en) | 2011-02-25 | 2015-09-15 | Alstom Technology Ltd | Systems and processes for removing volatile degradation products produced in gas purification |
| US8864878B2 (en) | 2011-09-23 | 2014-10-21 | Alstom Technology Ltd | Heat integration of a cement manufacturing plant with an absorption based carbon dioxide capture process |
| US8911538B2 (en) | 2011-12-22 | 2014-12-16 | Alstom Technology Ltd | Method and system for treating an effluent stream generated by a carbon capture system |
| US9028654B2 (en) | 2012-02-29 | 2015-05-12 | Alstom Technology Ltd | Method of treatment of amine waste water and a system for accomplishing the same |
| US9101912B2 (en) | 2012-11-05 | 2015-08-11 | Alstom Technology Ltd | Method for regeneration of solid amine CO2 capture beds |
Family Cites Families (10)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4434613A (en) * | 1981-09-02 | 1984-03-06 | General Electric Company | Closed cycle gas turbine for gaseous production |
| DE3501456A1 (en) * | 1985-01-17 | 1986-07-17 | Linde Ag, 6200 Wiesbaden | Process for reducing the SO2 and NOx content of gases |
| DE69206846T3 (en) * | 1991-03-07 | 1999-11-25 | Mitsubishi Jukogyo K.K., Tokio/Tokyo | Device and method for removing carbon dioxide from exhaust gases |
| US6148602A (en) * | 1998-08-12 | 2000-11-21 | Norther Research & Engineering Corporation | Solid-fueled power generation system with carbon dioxide sequestration and method therefor |
| DK1197258T3 (en) * | 2000-10-13 | 2011-04-04 | Alstom Technology Ltd | Procedure for operating a power plant |
| DK1197257T3 (en) * | 2000-10-13 | 2010-03-22 | Alstom Technology Ltd | Method and apparatus for providing hot working gases |
| JP3814206B2 (en) * | 2002-01-31 | 2006-08-23 | 三菱重工業株式会社 | Waste heat utilization method of carbon dioxide recovery process |
| US7284362B2 (en) * | 2002-02-11 | 2007-10-23 | L'Air Liquide, Société Anonyme à Directoire et Conseil de Surveillance pour l'Étude et l'Exploitation des Procedes Georges Claude | Integrated air separation and oxygen fired power generation system |
| EP1429000A1 (en) * | 2002-12-09 | 2004-06-16 | Siemens Aktiengesellschaft | Method and device for operating a gas turbine comprising a fossile fuel combustion chamber |
| DE102004061729A1 (en) * | 2003-12-19 | 2005-07-14 | Technische Universität Dresden | Desulfurization of carbon dioxide stream from carbon dioxide-free power station of oxy-fuel type involves condensing stream in flue gas desulfurization plant by means of cooled washing suspension |
-
2008
- 2008-06-26 WO PCT/GB2008/002190 patent/WO2009004307A1/en active Application Filing
- 2008-06-26 CA CA2697235A patent/CA2697235A1/en not_active Abandoned
- 2008-06-26 EP EP08762496A patent/EP2175964A1/en not_active Withdrawn
- 2008-06-26 AU AU2008272719A patent/AU2008272719A1/en not_active Abandoned
Also Published As
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|---|---|
| AU2008272719A1 (en) | 2009-01-08 |
| EP2175964A1 (en) | 2010-04-21 |
| WO2009004307A1 (en) | 2009-01-08 |
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