WO1999013967A1 - Installation de separation de co2 de gaz de combustion de turbine a gaz - Google Patents

Installation de separation de co2 de gaz de combustion de turbine a gaz Download PDF

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Publication number
WO1999013967A1
WO1999013967A1 PCT/GB1998/002773 GB9802773W WO9913967A1 WO 1999013967 A1 WO1999013967 A1 WO 1999013967A1 GB 9802773 W GB9802773 W GB 9802773W WO 9913967 A1 WO9913967 A1 WO 9913967A1
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WO
WIPO (PCT)
Prior art keywords
sea water
flue gas
outlet
supply member
separation vessel
Prior art date
Application number
PCT/GB1998/002773
Other languages
English (en)
Inventor
Bernt Helge Torkildsen
Martin Sigmundstad
Harald Linga
Finn Patrick Nilsen
Erik Nilsen
Original Assignee
Den Norske Stats Oljeselskap A.S
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
Priority claimed from GBGB9719668.7A external-priority patent/GB9719668D0/en
Priority claimed from GBGB9803864.9A external-priority patent/GB9803864D0/en
Application filed by Den Norske Stats Oljeselskap A.S filed Critical Den Norske Stats Oljeselskap A.S
Priority to AU90874/98A priority Critical patent/AU9087498A/en
Publication of WO1999013967A1 publication Critical patent/WO1999013967A1/fr

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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
    • B01D53/1493—Selection of liquid materials for use as 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
    • B01D53/1456—Removing acid components
    • 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
    • B01D53/14—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
    • B01D53/18—Absorbing units; Liquid distributors therefor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01F—MIXING, e.g. DISSOLVING, EMULSIFYING OR DISPERSING
    • B01F25/00—Flow mixers; Mixers for falling materials, e.g. solid particles
    • B01F25/30—Injector mixers
    • B01F25/31—Injector mixers in conduits or tubes through which the main component flows
    • B01F25/312—Injector mixers in conduits or tubes through which the main component flows with Venturi elements; Details thereof
    • B01F25/3124—Injector mixers in conduits or tubes through which the main component flows with Venturi elements; Details thereof characterised by the place of introduction of the main flow
    • B01F25/31241—Injector mixers in conduits or tubes through which the main component flows with Venturi elements; Details thereof characterised by the place of introduction of the main flow the main flow being injected in the circumferential area of the venturi, creating an aspiration in the central part of the conduit
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J10/00—Chemical processes in general for reacting liquid with gaseous media other than in the presence of solid particles, or apparatus specially adapted therefor
    • B01J10/002—Chemical processes in general for reacting liquid with gaseous media other than in the presence of solid particles, or apparatus specially adapted therefor carried out in foam, aerosol or bubbles
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J19/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J19/26—Nozzle-type reactors, i.e. the distribution of the initial reactants within the reactor is effected by their introduction or injection through nozzles
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J2219/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J2219/00049—Controlling or regulating processes
    • B01J2219/00051—Controlling the temperature
    • B01J2219/00074—Controlling the temperature by indirect heating or cooling employing heat exchange fluids
    • B01J2219/00087—Controlling the temperature by indirect heating or cooling employing heat exchange fluids with heat exchange elements outside the reactor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J2219/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J2219/00049—Controlling or regulating processes
    • B01J2219/00051—Controlling the temperature
    • B01J2219/00074—Controlling the temperature by indirect heating or cooling employing heat exchange fluids
    • B01J2219/00087—Controlling the temperature by indirect heating or cooling employing heat exchange fluids with heat exchange elements outside the reactor
    • B01J2219/00103—Controlling the temperature by indirect heating or cooling employing heat exchange fluids with heat exchange elements outside the reactor in a heat exchanger separate from the reactor
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J2219/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J2219/00049—Controlling or regulating processes
    • B01J2219/00051—Controlling the temperature
    • B01J2219/00074—Controlling the temperature by indirect heating or cooling employing heat exchange fluids
    • B01J2219/00105—Controlling the temperature by indirect heating or cooling employing heat exchange fluids part or all of the reactants being heated or cooled outside the reactor while recycling
    • B01J2219/0011—Controlling the temperature by indirect heating or cooling employing heat exchange fluids part or all of the reactants being heated or cooled outside the reactor while recycling involving reactant liquids
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J2219/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J2219/00049—Controlling or regulating processes
    • B01J2219/00051—Controlling the temperature
    • B01J2219/00159—Controlling the temperature controlling multiple zones along the direction of flow, e.g. pre-heating and after-cooling
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01J—CHEMICAL OR PHYSICAL PROCESSES, e.g. CATALYSIS OR COLLOID CHEMISTRY; THEIR RELEVANT APPARATUS
    • B01J2219/00—Chemical, physical or physico-chemical processes in general; Their relevant apparatus
    • B01J2219/00049—Controlling or regulating processes
    • B01J2219/00164—Controlling or regulating processes controlling the flow
    • 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 present invention relates to the removal of C0 2 from the flue gas from a gas turbine electricity generating plant.
  • solvents include amines such as methyldiethanolamine (MDEA), monoethanolamine (MEA) or diethanolamine (DEA) and mixtures of solvents. These solvents absorb CO 2 , NO x , H2S and other acid gases.
  • MDEA methyldiethanolamine
  • MEA monoethanolamine
  • DEA diethanolamine
  • the solvent is contacted with the sour gas mixture (gas mixture including acid gases) in a column which may be a packed column, a plate column or a bubble- cap column, or a column with some other form of contact medium.
  • the gas and liquid streams flow countercurrently.
  • apparatus for separating carbon dioxide from flue gas comprising a sea water supply member, a flue gas supply member, a plurality of turbulent contactors and a gas/liquid separation vessel, in which: each turbulent contactor comprises a housing, a sea water inlet from the sea water supply member, a flue gas inlet from the flue gas supply member, an outlet leading to a venturi passage and a tube within the housing extending from the outlet back upstream, the tube being perforated and/or being spaced from the outer periphery of the outlet; each venturi passage extends into an elongate contact pipe which communicates with the interior of the separation vessel; and the separation vessel has a cleaned gas outlet and a used sea water outlet.
  • the flue gas is brought into contact with the sea water in the turbulent contactors where the turbulent mixing conditions cause part of the C0 2 to be absorbed. Further absorption takes place in the contact pipes.
  • the gaseous and liquid phases are separated in the separator vessel into a cleaned flue gas and the used or C0 2 -loaded sea water.
  • the system is capable of removing 40% or more of the CO 2 present.
  • seawater as an absorbing medium, leads to a considerably simpler process with lower installation and operational costs than a CO 2 -removal plant based on e.g. chemical absorption of CO 2 in an amine solvent. There may also be no need to treat the loaded sea water to remove the absorbed C0 2 since sea water is plentiful and does not need to be recovered for re-use.
  • the turbulent mixing is very intense and results in extremely efficient gas liquid contact.
  • the liquid entrained in the gas may be in the form of droplets for gas continuous fluid phase distribution.
  • the efficient mixing means that absorption can take place very rapidly.
  • the mixing system used is simple and inexpensive compared to prior art systems, and requires no solvent regeneration.
  • the method is carried out as a continuous process with the flue gas and sea water flowing co-currently.
  • the co-current flow eliminates the problems associated with foaming, and separation is effected without difficulty downstream of the contactors in the separation vessel.
  • the separation vessel is generally cylindrical and arranged with its axis generally vertical, and the sea water supply member is a pipe extending upwards with the separation vessel.
  • the turbulent contactors and contact pipes are arranged circumferentially around the separation vessel, extending generally vertically with the inlets to the turbulent contactors in their respective upper parts and the communication between the contact pipes and the separation vessel being a direct connection at the bottom of each contact pipe.
  • the flue gas supply member is a manifold connected to the flue gas inlet of each turbulent contactor.
  • the tube is located in a housing which includes the gas inlet, the liquid inlet and the outlet.
  • the flue gas is supplied to the tube, preferably directly, and the sea water is supplied to the housing and so the gas stream draws the sea water into the venturi and the two phases are mixed.
  • the end of the tube defines the inner periphery of the outlet.
  • the flue gas is supplied to the housing and the sea water is supplied to the tube, optionally directly, whereby the flue gas is drawn into the venturi by the sea water and the two phases are mixed.
  • the sea water and the flue gas are supplied to the housing, the sea water being supplied to a level above the level of the outlet, whereby the flue gas is forced out through the outlet via the tube, thereby drawing the sea water into venturi so that the two phases are mixed.
  • one or several secondary mixer stages can be installed to maintain the gas/liquid mixing efficiency.
  • the flue gas and the sea water are formed into a homogeneous mixture in the contactor, and the homogeneous mixture may be cooled prior to separation into a gas phase and a liquid phase.
  • the cooled homogeneous mixture is then separated into a gas phase and a liquid phase in the gas-liquid separator vessel.
  • an installation for removing and disposing of carbon dioxide from flue gas from a gas turbine electricity generating plant which comprises: apparatus for separating carbon dioxide from the flue gas comprising a sea water supply member, a flue gas supply member, a gas/liquid separation vessel having a cleaned gas outlet and a used sea water outlet, and a plurality of turbulent contactors, each having respective inlets from the sea water and flue gas supply members and an outlet to the separation vessel; means for supplying sea water to the sea water supply member; means for supplying the flue gas to the flue gas supply member; and means for transporting used sea water from the used sea water outlet back to the sea.
  • the CO 2 separation is effected by means of the separation apparatus described above.
  • the means for supplying sea water is a sea water lift pump.
  • the flue gas supply member is a flue gas manifold and the means for supplying flue gas is a fan connecting duct to the gas turbine exhaust.
  • the means for transporting used sea water is a transport pump and associated piping arranged to open beneath the sea at a depth of at least 100m. In cases of flue gas purification at low pressure, the sea water is pumped to the contactors and can thereby draw the combustion gas with it through the contactors.
  • the system may include a pump for the flue gas so that the flue gas is conveyed to the contactors at a high pressure and thereby draws the sea water with it through the contactors.
  • the invention may be considered to extend to the use of sea water and the apparatus and installation described in order to remove CO 2 from flue gas, and to return C0 2 -loaded sea water to the environment at an appropriate location and depth.
  • Figure 1 is a schematic view of an installation in accordance with the invention
  • Figure 2 is an elevation of a CO 2 separator arrangement
  • Figure 3 is a perspective view of the separator arrangement of Figure 2;
  • Figure 4 is a simplified vertical section through the separator arrangement
  • Figure 5 is a block diagram of the apparatus used in a series of experiments
  • Figure 6 is a schematic diagram of a sampling point
  • FIG 7 is a simplified section through the contactor used in the experiments.
  • the installation shown in Figure 1 comprises a flue gas inlet 11, and a sea water supply 12.
  • the flue gas first passes through a primary heat recovery unit 13 and then a heat exchanger 14 on its way to a low pressure fan 15.
  • the fan 15 conveys the flue gas to a CO 2 separator arrangement 16 comprising a mixing unit 17 and a gas/liquid separation vessel 18. Sea water is also conveyed to the separator arrangement 16 by a lift pump 19.
  • the flue gas and sea water first enter the mixing unit 17 where turbulent mixing takes place, producing a homogenous mixture.
  • C0 2 in the flue gas is absorbed by the sea water and the mixture is conveyed immediately to the separation vessel 18.
  • cleaned flue gas is obtained and discharged in a discharge line 21 via the heat exchanger 14.
  • CO 2 -loaded sea water is also obtained and is discharged back into the sea by a transport pump 22 via a used sea water line 23.
  • a part of the sea water may also be re-routed to the gas/liquid mixer in order to gain a higher CO 2 loading of the liquid pumped back into the sea. This serves to increase the energy efficiency of the CO 2 removal (power consumed per mass CO 2 removed). Attention is drawn to the present applicants co-pending application number (Our case P20557WO) entitled "Separation of acid gases from combustion gas".
  • the heat recovery unit 13 is a standard gas turbine waste heat recovery unit using sea water as the coolant.
  • the heat exchanger 14 is a gas/gas conventional Advanced Plate-type heat exchanger.
  • the fan 15 comprises a pair of compressor units, each having an inlet flow equal to half the total flow.
  • the lift pump 19 comprises a pair of standard electric submersible pumps providing a flow rate of about 10,000 to 15,000 m7hr. Alternatively, existing sea water cooling pumps could be employed to provide the necessary sea water for the process.
  • the transport pump 22 may be similar to the pump 19, though other pump designs could be employed.
  • the separator arrangement 16 is shown in more detail in Figures 2 to 4. It comprises essentially a series of (in this case, fourteen) turbulent contactors 31, each leading down directly to a respective vertical contact pipe 32, and a common separation vessel 33.
  • the separation vessel 33 is generally cylindrical with its axis vertical and the contactors 31 and their contact pipes 32 are arranged around its periphery.
  • a sea water inlet pipe 34 receives sea water from the lift pump 19 and leads to a distribution column 35 within the separation vessel 33.
  • a flue gas inlet pipe 36 receives flue gas from the fan 15 and leads to a flue gas manifold 37.
  • the separation vessel 33 has a cleaned gas outlet 38 at the top leading to the outlet line 21 and a used sea water outlet 39 at the bottom leading to line 23.
  • Each turbulent contactor 31 comprises a frusto-conical housing 41 having a sea water inlet 42 connected to the column 35 via a radial pipe 43, and a flue gas inlet pipe 45 connected to the manifold 37.
  • the flue gas inlet pipe 45 extends into a tube 48 within the housing 41 and together with the wall of the housing 41, defines an annular outlet 46 leading to a venturi passage 47.
  • the venturi passage 47 opens into the contact pipe 32 which in turn opens into the bottom of the separation vessel 33.
  • the liquid entering the ttirbulent contactor may also have one or more non-radial liquid inlets 43 in the sense that the inlets are circularly located in the same plane and are fed by a centrally or non- centrally located distribution column 35.
  • sea water is supplied to the contactors 31 by the lift pump 19 via the inlet pipe 34, the column 35 and the radial pipes 43, while flue gas is supplied to the contactors by the fan 15 via the inlet pipe 36, the manifold 37 and the feed pipes 45.
  • Turbulent mixing takes place in the contactors 31 and as the homogeneous gas/liquid mixture leaves the venturi passages, further contact takes place in the contact pipes 32. This results in C0 2 from the flue gas being absorbed by the sea water.
  • the mixture is conveyed to the separation vessel 33 where the two phases separate out into a cleaned gas and C0 2 -loaded sea water.
  • the cleaned gas is removed via the gas outlet 38.
  • the CO content is sufficiently low for the gas to be discharged to atmosphere.
  • the CO 2 -loaded sea water is removed via the outlet 39 and is returned to the sea by the transport pump 22 at a distance of 8km and a depth of 33m.
  • the absorbed C0 2 remains in solution and is dispersed.
  • the contactor used was a FRAMO contactor generally as described in EP 379319 and shown in Figure 7.
  • the turbulent contactor 100 comprises a vessel 101 having a gas inlet 102, a liquid inlet 103 and an outlet 104 leading to a venturi passage 105.
  • the mixer injection pipe was adjusted to yield gas/liquid ratios in the range of about 4.5 to about 14, depending on the total flow rate.
  • a schematic diagram of the apparatus for the series of experiments is shown in Figure 5.
  • the apparatus in Figure 5 comprises a contactor 51, corresponding to that shown in Figure 7, a vertical pipe section 56 leading from the venturi 52, and a horizontal pipe section 59 joining the vertical section 56 to a receiver 61.
  • the vertical section 56 has two quick closing valves 57,58.
  • a sea water tank 54 leads to the contactor 51 via a valve 55.
  • a diesel engine 75 has its exhaust connected to the contactor via a line 71 including an orifice plate 74.
  • the line 71 is provided with a by-pass valve 70 in a by-pass line 72.
  • the receiver 61 is slightly inclined and has a liquid drain 65 at its lowest point, leading to a tank 67 via a valve 66.
  • the tank 67 has an outlet 68 with a valve 69.
  • the receiver 61 also has a gas cylinder 62 (not used) which can be used to pressurise the reservoir 61 via a line 63 with a valve 64. Measurements are taken variously at eight sampling points designated SP in Figure 5. Exhaust is located at the exhaust entry to the contactor 51. SP, is 1 metre after the contactor with SP 2 and SP within the next 1.5 metres. SP 4 is in the horizontal portion 59, SP 5 is at the entry to the receiver 61 and SP 6 is at the opposite end of the receiver 61. The final SP 7 is in the receiver outlet.
  • Each sampling point comprises a centrally located sampling tube 81 opening in the downstream direction and protected by a cap 82.
  • the cap serves to reduce liquid entrainment in the gas sample.
  • the sampling tube leads to a hydrocyclone 83 which removes any residual moisture so that dry gas leaves the gas outlet 84 for analysis.
  • the contactor 51 and pipe section 56 were charged with sea water taken from a Norwegian fjord. Exhaust gas from a YA NMAR 4TN84E 15 KVA water-cooled diesel engine 75 was used as the feed gas. A 30% load was placed on the diesel engine to increase the exhaust gas temperature and also to obtain a higher level of C0 2 on the exhaust gas.
  • the orifice plate 74 provided for continuous flow measurement of the exhaust gas.
  • the approach was based on sampling continuous flow in the pipe.
  • the sampling probes were situated in the centre of the pipe with a cover, which accommodated the retrieval of a gas/liquid sample with low liquid content. This two-phase flow from each sampling was then routed through a gas/liquid cyclone from which a dry gas sample was taken from the gas outlet. [This arrangement with the sampling probe described was repeated in seven different locations downstream of the first contactor as well as in the exhaust feed entering the contactor.] The sampling locations are shown on Figure 5 and referred to in Table 2.
  • the experiments were carried out either by pre-filling the first stage contactor with sea water and/or continuously supplying sea water from the fjord. In the former case, experiments have been carried out with different levels of sea water temperature.

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

Abstract

L'invention concerne un appareil de séparation de dioxyde de carbone d'un gaz de combustion, l'appareil comprenant un élément d'alimentation en eau de mer (35), un élément d'alimentation en gaz de combustion (37), plusieurs contacteurs à turbulence (31) et un récipient de séparation (33) gaz/liquide. Chaque contacteur à turbulence (31) comprend un logement (41), un orifice d'admission d'eau de mer (42) provenant de l'élément d'alimentation en eau de mer (35), un orifice d'admission de gaz de combustion (45) provenant de l'élément d'alimentation en gaz de combustion (37), un orifice d'évacuation (46) conduisant à un passage venturi (47) et un tube (48) situé à l'intérieur du logement (41) et s'étendant de l'orifice d'admission (46) vers l'arrière en amont. Le tube (48) est perforé et/ou séparé de la périphérie de l'orifice d'évacuation (46) et peut définir l'orifice d'évacuation (46).Chaque passage de venturi (47) s'étend en un tuyau de contact allongé (32) qui communique avec l'intérieur du récipient de séparation (33). Le récipient de séparation (33) possède un orifice d'évacuation de gaz purifié (38) et un orifice d'évacuation d'eau de mer usée (39).
PCT/GB1998/002773 1997-09-15 1998-09-14 Installation de separation de co2 de gaz de combustion de turbine a gaz WO1999013967A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU90874/98A AU9087498A (en) 1997-09-15 1998-09-14 Installation for separation of co2 from gas turbine flue gas

Applications Claiming Priority (10)

Application Number Priority Date Filing Date Title
GB9719668.7 1997-09-15
GBGB9719668.7A GB9719668D0 (en) 1997-09-15 1997-09-15 Acid gas separation
GB9800480.7 1998-01-09
GB9800483.1 1998-01-09
GBGB9800484.9A GB9800484D0 (en) 1997-09-15 1998-01-09 Separation of acid gas from combustion gases
GBGB9800483.1A GB9800483D0 (en) 1997-09-15 1998-01-09 Separation of acid gas from natural gas
GB9800484.9 1998-01-09
GBGB9800480.7A GB9800480D0 (en) 1997-09-15 1998-01-09 Fluid separation system
GBGB9803864.9A GB9803864D0 (en) 1997-09-15 1998-02-24 Separation of acid gases from gas mixtures
GB9803864.9 1998-02-24

Publications (1)

Publication Number Publication Date
WO1999013967A1 true WO1999013967A1 (fr) 1999-03-25

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PCT/GB1998/002773 WO1999013967A1 (fr) 1997-09-15 1998-09-14 Installation de separation de co2 de gaz de combustion de turbine a gaz

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AU (1) AU9087498A (fr)
WO (1) WO1999013967A1 (fr)

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WO2002004099A1 (fr) * 2000-07-11 2002-01-17 Marioff Corporation Oy Systeme de purification des gaz d'echappement de moteurs a combustion interne
US7735274B2 (en) 2007-05-24 2010-06-15 Calera Corporation Hydraulic cements comprising carbonate compound compositions
US7744761B2 (en) 2007-06-28 2010-06-29 Calera Corporation Desalination methods and systems that include carbonate compound precipitation
US7749476B2 (en) 2007-12-28 2010-07-06 Calera Corporation Production of carbonate-containing compositions from material comprising metal silicates
US7754169B2 (en) 2007-12-28 2010-07-13 Calera Corporation Methods and systems for utilizing waste sources of metal oxides
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US7771684B2 (en) 2008-09-30 2010-08-10 Calera Corporation CO2-sequestering formed building materials
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US7815880B2 (en) 2008-09-30 2010-10-19 Calera Corporation Reduced-carbon footprint concrete compositions
US7829053B2 (en) 2008-10-31 2010-11-09 Calera Corporation Non-cementitious compositions comprising CO2 sequestering additives
US7875163B2 (en) 2008-07-16 2011-01-25 Calera Corporation Low energy 4-cell electrochemical system with carbon dioxide gas
US7887694B2 (en) 2007-12-28 2011-02-15 Calera Corporation Methods of sequestering CO2
US7939336B2 (en) 2008-09-30 2011-05-10 Calera Corporation Compositions and methods using substances containing carbon
US7966250B2 (en) 2008-09-11 2011-06-21 Calera Corporation CO2 commodity trading system and method
US7993511B2 (en) 2009-07-15 2011-08-09 Calera Corporation Electrochemical production of an alkaline solution using CO2
US7993500B2 (en) 2008-07-16 2011-08-09 Calera Corporation Gas diffusion anode and CO2 cathode electrolyte system
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US8137444B2 (en) 2009-03-10 2012-03-20 Calera Corporation Systems and methods for processing CO2
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