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WO1994016992A1 - Cycle de puissance combine respectant l'environnement - Google Patents

Cycle de puissance combine respectant l'environnement Download PDF

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Publication number
WO1994016992A1
WO1994016992A1 PCT/US1993/011644 US9311644W WO9416992A1 WO 1994016992 A1 WO1994016992 A1 WO 1994016992A1 US 9311644 W US9311644 W US 9311644W WO 9416992 A1 WO9416992 A1 WO 9416992A1
Authority
WO
WIPO (PCT)
Prior art keywords
flue gas
turbine
water vapor
gas
further characterized
Prior art date
Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
Ceased
Application number
PCT/US1993/011644
Other languages
English (en)
Inventor
Leon Awerbuch
Jack Z. Abrams
Bruce R. Gilbert
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Bechtel Group Inc
Original Assignee
Bechtel Group Inc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Bechtel Group Inc filed Critical Bechtel Group Inc
Priority to AU56836/94A priority Critical patent/AU5683694A/en
Publication of WO1994016992A1 publication Critical patent/WO1994016992A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

Links

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
    • B01D53/34—Chemical or biological purification of waste gases
    • B01D53/46—Removing components of defined structure
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B01D53/501—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound
    • 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
    • B01D53/48—Sulfur compounds
    • B01D53/50—Sulfur oxides
    • B01D53/501—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound
    • B01D53/504—Sulfur oxides by treating the gases with a solution or a suspension of an alkali or earth-alkali or ammonium compound characterised by a specific device
    • 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
    • F01K21/047—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 having at least one combustion gas turbine
    • B—PERFORMING OPERATIONS; TRANSPORTING
    • B01—PHYSICAL OR CHEMICAL PROCESSES OR APPARATUS IN GENERAL
    • B01D—SEPARATION
    • B01D2252/00—Absorbents, i.e. solvents and liquid materials for gas absorption
    • B01D2252/10—Inorganic absorbents
    • B01D2252/103—Water
    • B01D2252/1035—Sea water
    • 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

Definitions

  • the present invention discloses a power cycle based on the use of fuel oil (crude or residual) as the fuel for a combustion gas turbine in areas where gas is not readily available and a scrubber combined with the turbine for cleaning the exhaust gases from the burner section of the turbine of undesirable contaminants produced by the combustion of such fuel oil in the turbine to an environmentally acceptable condition for exhausting to the atmosphere while concurrently producing condensate for use in the turbine or with fuel used to fire the turbine.
  • fuel oil crude or residual
  • U.S. Patent 4,804,523 issued Feb. 14, 1989 to the assignee of the present invention provides for efficient removal of sulfur dioxide from a flue gas stream in a scrubber using a recirculating aqueous stream containing magnesium hydroxide and magnesium sulfite which together act as S0 2 absorbents.
  • M agnesium sulfite is derived from magnesium hydroxide, which is the product of a reaction between soluble magnesium from the sea water and calcium hydroxide added to the scrubbing system.
  • Magnesium sulfite and bisulfite are oxidized to magnesium sulfate by the introduction of air. Magnesium sulfate is converted back to magnesium hydroxide by reaction with additional calcium hydroxide, with gypsum as a by ⁇ product. Gypsum is soluble in large amounts of sea water and may be returned to the ocean without adverse environmental impact.
  • U.S. Patent No. 4,337,230 issued June 29, 1982 disclosed a method of absorbing sulfur oxides from flue gases in sea water, comprising adding to the sea water calcium based alkali subsequent to the absorption, and then introducing the sea water to which alkali has been supplied into a decarbonation/oxidation reactor to which an oxygen-containing gas is supplied in order to oxidize sulfur oxides in the sea water and to strip carbon dioxide from the sea water.
  • a decarbonation/oxidation reactor to which an oxygen-containing gas is supplied in order to oxidize sulfur oxides in the sea water and to strip carbon dioxide from the sea water.
  • calcium based alkali is again added to the sea water in order to increase its pH.
  • a waste flue gas desulfurizing method is described in U.S. Patent 4,085,194 issued April 18, 1978 in which a waste flue gas containing sulfurous acid gas is contacted directly with sea water, whereby the sulfurous acid gas is absorbed in the sea water and concurrently sulfites are formed in the sea water by the reaction between the sulfurous acid ions and metal ions present in the sea water, and then the carbonic acid component contained in the sea water which is then in the acidic region is released therefrom by a decarbonation operation to restore the pH value of the sea water in the neutral region, and thereafter oxygen contained in air or from other source is introduced into the sulfite- containing sea water to convert said sulfites into sulfates.
  • a desulphurization process in which acid components of waste gas are removed by spray drying absorption, using an aqueous suspension of slaked lime or limestone as absorbent with recycling of part of the reaction product to the absorbent, is controlled on the basis of determination of the chloride content of the aqueous suspension including recycled reaction product.
  • the chloride content of the absorbent is used as the basis for (a) controlling the amount of chloride in the aqueous suspension to such a value that a specific chloride content of the spray dried product is between 1 and 7% by weight, and, within this range is related to the difference between the temperature of the desulfurized waste gas and the adiabatic saturation temperature thereof, and/or (b) for controlling the quantity of water evaporated by the spray drying, which is also related to the set forth chloride content, to change the difference between the temperature of the desulfurized waste gas and the adiabatic saturation temperature thereof, to provide a minimum temperature difference so as to maximize the acid base reaction yet maintain an actual temperature difference high enough to avoid sticky products.
  • the present invention is directed to a combined power cycle utilizing a gas turbine capable of operating on a crude oil or residual oil fuel combined with a scrubbing process for removing environmentally undesirable contaminants from the gaseous exhaust from the oil fired gas turbine. Turbine efficiency and fuel oil acceptability are also improved utilizing the combined power environmental cycle of the present invention.
  • the invention provides a method for producing power using liquid fuel oil wherein the liquid fuel oil is combusted in a combustion gas turbine.
  • Hot flue gases exhausted from the turbine contain sulfur dioxide and water vapor as products of combustion.
  • the hot flue gases are flowed to a sea water scrubber where sulfur dioxide is removed f rom the hot flue gases to produce a clean flue gas including water vapor contained therein.
  • the clean flue gas is directed to a flue gas condenser having a sea water heat exchange tube where the water vapor portion of the clean flue gas is condensed.
  • At least a portion of the condensed water vapor is made available as water or steam for injection into the combustion gas turbine to improve its efficiency and to lower the formation of undesirable products of combustion therein.
  • Another portion of the condensed water vapor is made available for cleaning the fuel oil prior to its use in the combustion gas turbine or for emulsifying the fuel oil into an oil-water emulsion to improve the burning characteristics of the fuel oil.
  • the present invention provides a combined power environmental cycle system for producing power using liquid fuel oil particularly where gas is not available to fire the gas turbine.
  • a combustion gas turbine is provided with burners adapted to be fired with liquid fuel oil.
  • the turbine has a turbine exhaust for exhausting hot flue gases which contain sulfur dioxide and water vapor.
  • a source of liquid fuel oil is operably connected to the burner section of the combustion turbine for combustion therein.
  • a sea water scrubber is provided and used for removing sulfur dioxide from hot flue gases.
  • the sea water scrubber has a flue gas inlet, a sea water intake port, a clean flue gas exit port and a liquid effluent exhaust port.
  • Conduit means are arranged to connect the turbine exhaust to the flue gas inlet of the sea water scrubber.
  • a sea water source connected by a conduit with the sea water intake port of the sea water scrubber.
  • a flue gas condenser having a sea water heat exchange tube is also connected to the sea water source by a suitable conduit.
  • the flue gas condenser has a sea water inlet, a sea water outlet and a condensate outlet.
  • the clean flue gas exit port of the sea water scrubber is connected to the flue gas condenser.
  • Conduits are operably connected between the condensate outlet of the flue gas condenser and the combustion turbine for making available condensate to the combustion turbine.
  • Conduit means are also operatively connected between the condensate outlet of the flue gas condenser and the source of liquid fuel for making available condensate for use with the liquid oil fuel.
  • fuel oil crude or residual
  • the combined power environmental cycle is schematically illustrated in the drawing. As these shown the power cycle is generally indicated by the area denoted as "A” in the drawing and the environmental cycle is generally indicated by the area denoted as "B” .
  • the cycles are combined to permit use of crude oil or residual oil to fire a combustion gas turbine in areas where gas is not readily available and to provide environmentally acceptable effluents for exhausting from the cycle.
  • Condensate recovered from the environmental cycle is made available for use in the turbine either as injected steam or injected water to improve turbine efficiency and to reduce the formation of undesirable products of combustion in the burner section of the gas turbine. Condensate may also be made available for use with the fuel oil to clean it or to emulsify it to improve the combustion efficiency of the fuel oil in the turbine.
  • the use of crude or residual oil as a fuel for gas turbines is well known. However, the turbine exhaust when using oil as a fuel contains levels of N0 ⁇ and S0 2 which do not meet environmental standards and therefore must be treated before being released.
  • Table 1 shows an analysis of a typical washed crude oil useful as a fuel in accordance with the invention.
  • burning of crude oil in a gas turbine can produce an exhaust gas that must be treated before it can be released.
  • a gas turbine is shown and identified generally by the numeral 8.
  • the gas turbine includes a compression section 14, a burner section 10 and an expansion section 16.
  • the burner section 10 of the turbine 8 is adapted for burning crude oil or residual oil rather than gas as a fuel. Such conversions are well known in the art and generally require conversion to oil burners and an oil injection system.
  • Fuel oil is supplied to the burner section of the turbine 8 via fuel line 12.
  • Compressed air is supplied to the burner section 10 by the compression section 14.
  • the hot exhaust gas produced by the burner section 10 may, for example, be used by the expander section 16 of the turbine to drive a generator 18.
  • the hot flue gas is flowed from the burner section 10 via conduit 11 to the expansion section 16.
  • the hot flue gases exhausted from expansion chamber 16 of the gas turbine are directed to a heat recovery steam generator 20 via line 13 and used as a heat exchange fluid as described later in more detail to provide steam for use in the gas turbine.
  • a booster fan is connected to the outlet of the heat recovery steam generator 20 by conduit 15 for receiving the flue gas therefrom.
  • the booster fan 22 increases the pressure of the flue gas to a value suitable for injection into a sea water scrubber generally indicated by the number 26.
  • venturi scrubber shown in phantom as 23 in the drawing.
  • a venturi prescrubber should be utilized before the flue gas enters the sea water scrubber 26.
  • a venturi scrubber ahead of the sea water scrubber will remove and concentrate the metal oxides and separate them from the flue gas. Therefore these heavy metals will not be discharged into the seawater scrubber.
  • a selective catalytic reduction (SCR) system is advantageously used.
  • the SCR system would be installed downstream of the heat recovery steam generator as indicated in phantom in the drawing.
  • a preferred sea water scrubber for use in cleaning flue gas and a method of operating it are shown and described in U.S. Patent 4,804,523 which is assigned to the assignee of the present invention and briefly described in the prior art portion of this specification. The disclosure of U.S. Patent 4,804,522 is hereby incorporated herein by reference.
  • the sea water scrubber has been modified for use in the present invention as herein described.
  • Efficient removal of sulfur dioxide from a flue gas stream is achieved in a scrubber using a recirculating aqueous stream containing magnesium hydroxide and magnesium sulfite which together act as S0 2 absorbents.
  • Magnesium sulfite is derived from magnesium hydroxide, which is the product of a reaction between soluble magnesium from the sea water and calcium hydroxide added to the scrubbing system.
  • Magnesium sulfite and bisulfite are oxidized to magnesium sulfate by the introduction of air.
  • Magnesium sulfate is converted back to magnesium hydroxide by reaction with additional calcium hydroxide, with gypsum as a by-product.
  • Gypsum is soluble in large amounts of sea water and may be returned to the ocean without adverse environmental impact.
  • the seawater scrubber as described herein may be replaced by a conventional wet scrubber with magnesium hydroxide and magnesium sulfite as S0 2 absorbent, in a liquid closed loop system.
  • This is made possible by the internal regeneration of Mg(OH) 2 from the magnesium sulfate effluent with the added Ca(0H) 2 in a stoichiometric ratio with the amount of S0 2 removed (see U.S. Patent 4,804,523 issued February 14, 1989 to the assignee of the present invention) .
  • the solid by-product CAS0 4 .2H 2 0 (gypsum) can be dewatered and sold or disposed of as landfill.
  • the recovery of the water vapors from the flue gas as condensate - when seawater is not available for cooling can be made by using cooling towers wet or dry.
  • the sea water scrubber 26 receives the dirty flue gas from blower fan 22 via conduit 34 which enters the top of the scrubber.
  • the flue gas is flowed down the scrubber via central duct 35 and is discharged near the bottom of the scrubbing tower 32.
  • the flue gas then flows upwardly through contact trays 43 generally in a counter current direction relative to the flow of absorbent downward through the tower 32.
  • the absorbent may take the form of fresh sea water and other chemicals as described heretofore and is introduced into the tower via line 39 and spray nozzles 40.
  • the flue gas continues upwardly through the tower 32 and is eventually discharged through the clean flue conduit 33.
  • a sump 30 of absorbent fluid is maintained at the bottom of the tower 32.
  • a recirculation pump 36 is connected to the sump through a section line 37.
  • the absorbent passing through the pump is primarily recirculated through line 38 to spray nozzles 40, 42.
  • a side stream 46 from pump 36 is mixed with fresh sea water passing through the flue gas condenser 50 and then directed to a suitable location for discharge.
  • the clean flue gas leaving the sea water scrubber via line 33 contains a substantial portion of water vapor.
  • the flue gas is directed to flue gas condenser 50 and is passed in heat exchange relationship with fresh cold sea water entering the flue gas condenser via line 39. Condensate is removed from the condenser 50 via conduit 52 for further use in accordance with the invention.
  • the flue gas exits the condenser 50 via line 54 and may be reheated in heater 56 and flared in exhaust stack 58.
  • An alternative to the flue gas condenser 50 for recovering distilled water is the direct cooling of the saturated flue gas stream with cooled distilled water, whereby at least a portion of the evaporated water in the flue gas stream condenses and combines with the pure distilled water to produce warm pure water.
  • a water/water cooler will be provided for this alternative.
  • the condensate leaving the flue gas condenser via conduit 52 may be used as distilled water in the power cycle or to produce distillate products.
  • Appropriate pumps 60 and 62 and conduits 64 and 66 are provided to move the condensate to facilitate such uses.
  • Condensate is returned to the power cycle by condensate pump 60 via conduit 64.
  • the condensate is treated in polishing unit 68 to remove or convert scale forming ions to non scale forming ions.
  • the polishing unit with its mixed bed of anions resins and cations resins, will convert scale forming ions to non-scale forming ions.
  • Condensate exits polishing unit 68 via conduit 70 and may be divided into three streams via conduits 72, 74, 76. Condensate is made availa b le for washing or emulsifying the crude oil/residual oil liquid fuel via conduit 72. Conventional washing or emulsifying equipment may be used to wash or emulsify the fuel oil.
  • Condensate may also be directly injected into the combustion section 10 of the combustion turbine via conduit
  • Injection of condensate (i.e., distilled water) into the combustion section of a gas turbine reduces NO ⁇ emissions in the hot flue gases exiting the turbine. This is particularly important when liquid fuel is used in a gas turbine. Injection of condensate directly or as steam as later described into the combustion section of a gas turbine in a CPE cycle can reduce N0 ⁇ emissions from 220 ppm to about 40 ppm.
  • condensate i.e., distilled water
  • condensate is flowed via conduit 76 to the heat recovery steam generator 20 for conversion into steam.
  • a portion of such steam is made available via conduit 80 for injection into the burner section 10 and/or the expansion section 16 of the gas turbine to improve the efficiency thereof.
  • a second portion of the steam generated in the heat recovery steam generator 20 is flowed via conduit 82 to a steam turbine 84 which may be used to drive generator 86.
  • the effluent from steam turbine 84 is passed through a steam turbine condenser 90 via conduit 88.
  • the effluent is condensed and returned to condensate return conduit 64 via conduit 92 for recycling.
  • a condensate booster pump 94 may be added to the condensate return line 64 if needed.
  • the present invention broadly provides a method for producing power in an environmentally satisfactory manner using crude or residual oil in a gas turbine.
  • the hot flue gases containing sulfur dioxide and water vapor are exhausted from the gas turbine and flowed to a sea water scrubber.
  • Sea water is used in the sea water scrubber to remove sulfur dioxide from the hot flue gases to produce a clean flue gas including water vapor contained therein.
  • the water vapor is condensed and the condensate is made available for injection into the gas turbine and for use with the liquid fuel.
  • a particular advantage of the present invention is that crude fuel oil or residual oil, which are about 50% of the cost of refined oil, can be burned more efficiently by the cycle of the present invention than by any other process. Further the C0 2 emissions per kw/hr produced is the lowest in comparison with coal fired units or crude or residual oil burned in a boiler.
  • Other advantages and uses of the present invention will be apparent to those skilled in the art.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • General Chemical & Material Sciences (AREA)
  • Environmental & Geological Engineering (AREA)
  • Biomedical Technology (AREA)
  • Analytical Chemistry (AREA)
  • Health & Medical Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Treating Waste Gases (AREA)

Abstract

Cycle de puissance combiné respectant l'environnement dans lequel on utilise comme combustible pour une turbine (8) à gaz du pétrole brut ou des résidus de raffinage des huiles dans des zones dans lesquelles le gaz n'est que peu disponible pour produire de la puissance, et un épurateur (26) qui épure les gaz brûlés rejetés par la turbine à gaz jusqu'à un niveau acceptable pour l'environnement lorsqu'on les libère et qui produit simultanément du condensat destiné à être utilisé dans la turbine et avec le combustible servant à lancer la turbine.
PCT/US1993/011644 1993-01-25 1993-12-01 Cycle de puissance combine respectant l'environnement Ceased WO1994016992A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU56836/94A AU5683694A (en) 1993-01-25 1993-12-01 Combined power environmental cycle (cpec)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US1025793A 1993-01-25 1993-01-25
US08/010,257 1993-01-25

Publications (1)

Publication Number Publication Date
WO1994016992A1 true WO1994016992A1 (fr) 1994-08-04

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PCT/US1993/011644 Ceased WO1994016992A1 (fr) 1993-01-25 1993-12-01 Cycle de puissance combine respectant l'environnement

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AU (1) AU5683694A (fr)
WO (1) WO1994016992A1 (fr)

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US6406219B1 (en) 2000-08-31 2002-06-18 Jolyon E. Nove Greenhouse gas emission disposal from thermal power stations
EP1091095A3 (fr) * 1999-10-05 2003-02-26 Mitsubishi Heavy Industries, Ltd. Système de turbine à gaz et centrale combinée comprenant une telle turbine
WO2011067784A1 (fr) * 2009-12-02 2011-06-09 Kumar Subrahmanyam Procédé et système d'élimination de la chaleur, de lavage, de nettoyage et de neutralisation d'un milieu acide présent dans un gaz d'évacuation d'un combustible fossile
US8056318B2 (en) * 2007-11-08 2011-11-15 General Electric Company System for reducing the sulfur oxides emissions generated by a turbomachine
CN102343209A (zh) * 2011-09-28 2012-02-08 西安交通大学 应用锅炉排污水的烟气海水脱硫系统
US8397483B2 (en) 2008-10-27 2013-03-19 General Electric Company Inlet system for an EGR system
EP2703063A1 (fr) * 2012-09-04 2014-03-05 Alstom Technology Ltd Désulfuration et refroidissement de gaz de procédé
WO2014137647A1 (fr) * 2013-03-08 2014-09-12 Exxonmobil Upstream Research Company Traitement de l'échappement à utiliser dans une récupération de pétrole améliorée

Families Citing this family (1)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0881934A4 (fr) * 1996-10-16 1999-12-22 Jolyon Emanuel Nove Procede pour melanger les emissions de gaz a effet de serre provenant de centrales thermiques cotieres

Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4804523A (en) * 1987-06-17 1989-02-14 Bechtel Group, Incorporated Use of seawater in flue gas desulfurization
US5075085A (en) * 1989-05-15 1991-12-24 Mitsubishi Jukogyo Kabushiki Kaisha Desulfurizing method for exhaust gas from combustor
US5085843A (en) * 1989-07-17 1992-02-04 A/S Niro Atomizer Method of desulphurizing hot waste gas
US5141727A (en) * 1991-06-03 1992-08-25 Varney John W Flue gas treatment
US5198201A (en) * 1988-03-08 1993-03-30 Johnson Arthur F Removal of sulphur and nitrogen oxides from flue gases

Patent Citations (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4804523A (en) * 1987-06-17 1989-02-14 Bechtel Group, Incorporated Use of seawater in flue gas desulfurization
US5198201A (en) * 1988-03-08 1993-03-30 Johnson Arthur F Removal of sulphur and nitrogen oxides from flue gases
US5075085A (en) * 1989-05-15 1991-12-24 Mitsubishi Jukogyo Kabushiki Kaisha Desulfurizing method for exhaust gas from combustor
US5085843A (en) * 1989-07-17 1992-02-04 A/S Niro Atomizer Method of desulphurizing hot waste gas
US5141727A (en) * 1991-06-03 1992-08-25 Varney John W Flue gas treatment

Cited By (15)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1091095A3 (fr) * 1999-10-05 2003-02-26 Mitsubishi Heavy Industries, Ltd. Système de turbine à gaz et centrale combinée comprenant une telle turbine
US6406219B1 (en) 2000-08-31 2002-06-18 Jolyon E. Nove Greenhouse gas emission disposal from thermal power stations
US8056318B2 (en) * 2007-11-08 2011-11-15 General Electric Company System for reducing the sulfur oxides emissions generated by a turbomachine
US8397484B2 (en) 2008-10-27 2013-03-19 General Electric Company Inlet system for an EGR system
US8397483B2 (en) 2008-10-27 2013-03-19 General Electric Company Inlet system for an EGR system
US8402737B2 (en) 2008-10-27 2013-03-26 General Electric Company Inlet system for an EGR system
US8443584B2 (en) 2008-10-27 2013-05-21 General Electric Company Inlet system for an EGR system
WO2011067784A1 (fr) * 2009-12-02 2011-06-09 Kumar Subrahmanyam Procédé et système d'élimination de la chaleur, de lavage, de nettoyage et de neutralisation d'un milieu acide présent dans un gaz d'évacuation d'un combustible fossile
US8815187B2 (en) 2009-12-02 2014-08-26 Subrahmanyam Kumar Process and system for quenching heat, scrubbing, cleaning and neutralizing acidic media present in the flue gas from the firing of fossil fuel
CN102343209A (zh) * 2011-09-28 2012-02-08 西安交通大学 应用锅炉排污水的烟气海水脱硫系统
CN102343209B (zh) * 2011-09-28 2013-04-17 西安交通大学 应用锅炉排污水的烟气海水脱硫系统
EP2703063A1 (fr) * 2012-09-04 2014-03-05 Alstom Technology Ltd Désulfuration et refroidissement de gaz de procédé
WO2014137647A1 (fr) * 2013-03-08 2014-09-12 Exxonmobil Upstream Research Company Traitement de l'échappement à utiliser dans une récupération de pétrole améliorée
JP2016517491A (ja) * 2013-03-08 2016-06-16 エクソンモービル アップストリーム リサーチ カンパニー 原油二次回収に使用するための排気の処理
US9784140B2 (en) 2013-03-08 2017-10-10 Exxonmobil Upstream Research Company Processing exhaust for use in enhanced oil recovery

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Publication number Publication date
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