WO1993024703A1 - Procede de recuperation d'energie dans un gaz combustible - Google Patents

Procede de recuperation d'energie dans un gaz combustible Download PDF

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Publication number
WO1993024703A1
WO1993024703A1 PCT/SE1992/000363 SE9200363W WO9324703A1 WO 1993024703 A1 WO1993024703 A1 WO 1993024703A1 SE 9200363 W SE9200363 W SE 9200363W WO 9324703 A1 WO9324703 A1 WO 9324703A1
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WO
WIPO (PCT)
Prior art keywords
gas
heat
heat exchange
compressed air
gas turbine
Prior art date
Application number
PCT/SE1992/000363
Other languages
English (en)
Inventor
Lars Stigsson
Original Assignee
Chemrec Aktiebolag
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 to DE69226287T priority Critical patent/DE69226287T2/de
Priority to PCT/SE1992/000363 priority patent/WO1993024703A1/fr
Application filed by Chemrec Aktiebolag filed Critical Chemrec Aktiebolag
Priority to BR9207135A priority patent/BR9207135A/pt
Priority claimed from CA002136817A external-priority patent/CA2136817A1/fr
Priority to US08/343,555 priority patent/US5507141A/en
Priority to AU23210/92A priority patent/AU2321092A/en
Priority to EP92915554A priority patent/EP0642611B1/fr
Priority to JP6500439A priority patent/JPH08501605A/ja
Priority to CA002136817A priority patent/CA2136817A1/fr
Priority to PCT/SE1993/000212 priority patent/WO1993024704A1/fr
Priority to EP93909103A priority patent/EP0642612A1/fr
Priority to BR9306444A priority patent/BR9306444A/pt
Priority to CA002136829A priority patent/CA2136829A1/fr
Publication of WO1993024703A1 publication Critical patent/WO1993024703A1/fr
Priority to FI945602A priority patent/FI945602A/fi
Priority to FI945603A priority patent/FI945603A0/fi

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Classifications

    • D—TEXTILES; PAPER
    • D21—PAPER-MAKING; PRODUCTION OF CELLULOSE
    • D21C—PRODUCTION OF CELLULOSE BY REMOVING NON-CELLULOSE SUBSTANCES FROM CELLULOSE-CONTAINING MATERIALS; REGENERATION OF PULPING LIQUORS; APPARATUS THEREFOR
    • D21C11/00—Regeneration of pulp liquors or effluent waste waters
    • D21C11/12—Combustion of pulp liquors
    • D—TEXTILES; PAPER
    • D21—PAPER-MAKING; PRODUCTION OF CELLULOSE
    • D21C—PRODUCTION OF CELLULOSE BY REMOVING NON-CELLULOSE SUBSTANCES FROM CELLULOSE-CONTAINING MATERIALS; REGENERATION OF PULPING LIQUORS; APPARATUS THEREFOR
    • D21C11/00—Regeneration of pulp liquors or effluent waste waters
    • D21C11/12—Combustion of pulp liquors
    • D21C11/125—Decomposition of the pulp liquors in reducing atmosphere or in the absence of oxidants, i.e. gasification or pyrolysis
    • 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
    • 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
    • F01K23/00—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids
    • F01K23/02—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled
    • F01K23/06—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle
    • F01K23/067—Plants characterised by more than one engine delivering power external to the plant, the engines being driven by different fluids the engine cycles being thermally coupled combustion heat from one cycle heating the fluid in another cycle the combustion heat coming from a gasification or pyrolysis process, e.g. coal gasification
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C1/00—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid
    • F02C1/04—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F02—COMBUSTION ENGINES; HOT-GAS OR COMBUSTION-PRODUCT ENGINE PLANTS
    • F02C—GAS-TURBINE PLANTS; AIR INTAKES FOR JET-PROPULSION PLANTS; CONTROLLING FUEL SUPPLY IN AIR-BREATHING JET-PROPULSION PLANTS
    • F02C3/00—Gas-turbine plants characterised by the use of combustion products as the working fluid
    • F02C3/20—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products
    • F02C3/26—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products the fuel or oxidant being solid or pulverulent, e.g. in slurry or suspension
    • F02C3/28—Gas-turbine plants characterised by the use of combustion products as the working fluid using a special fuel, oxidant, or dilution fluid to generate the combustion products the fuel or oxidant being solid or pulverulent, e.g. in slurry or suspension using a separate gas producer for gasifying the fuel before combustion
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E20/00—Combustion technologies with mitigation potential
    • Y02E20/16—Combined cycle power plant [CCPP], or combined cycle gas turbine [CCGT]
    • Y02E20/18—Integrated gasification combined cycle [IGCC], e.g. combined with carbon capture and storage [CCS]
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02P—CLIMATE CHANGE MITIGATION TECHNOLOGIES IN THE PRODUCTION OR PROCESSING OF GOODS
    • Y02P70/00—Climate change mitigation technologies in the production process for final industrial or consumer products
    • Y02P70/10—Greenhouse gas [GHG] capture, material saving, heat recovery or other energy efficient measures, e.g. motor control, characterised by manufacturing processes, e.g. for rolling metal or metal working

Definitions

  • the present invention relates to an improved process for recovering energy from a combustible gas generated during gasification of cellulose waste liquors, the improvement comprising a cooling zone, wherein the combustible gas is cooled to a temperature below 150 C, simultaneously recovering sensible and latent heat in one or more heat exchangers, discharging the cooled combustible gas for use as fuel in a water and/or stea injected recuperative gas turbine cycle.
  • the raft process is currently the dominant chemical pulping process. During pulping large quantities of recoverable energy in the form of black liquor is generated. Worldwide some 2.8 billion GJ (780 TWh) of black liquor was produced in 1990 at kraft pulp mills.
  • the kraft recovery system has two principal functions:
  • the present invention relates to a major improvement in this area, using technology based on gasification and energy recovery in a recuperated gas turbine cycle.
  • Gasification of black liquor can be performed at vari ⁇ ous temperatures and pressures, resulting in different forms of the recovered inorganic constituents and different calorific values of the combustible process gas.
  • the inorganics mainly sodium compounds, are solubi- lized to form an aqueous alkaline liquid called green liquor, which liquor is used for cooking liquor prepa ⁇ ration.
  • Kraft pulp mills are significant producers of biomass energy and today most mills are designed to use the biomass fuel available at the kraft mill to meet on site steam and electricity needs via back pressure steam turbine cogeneration system. Electricity demand is often higher than internally generated, in particu ⁇ lar for integrated mills and often electricity is imported from the grit.
  • Process steam requirements for a modern kraft pulp mil is in the order of 10 GJ per ton of air dried pulp.
  • the internal electricity demand is around 600 kWh/ton of air dried pulp.
  • the biomass gasification gas turbine cogeneration system of the present invention will meet mill steam demand and has the potential to produce excess electri city for export.
  • the present invention can be practised using various types of gas generators and gasification principles exemplified in prior art documents.
  • gasification of spen cellulose liquor such as black liquor
  • the gasification temperature is in the range of 1000- 1300°C, resulting in the evolvement of molten inorga ⁇ nics and a combustible gas.
  • the molten alkaline chemi cals are withdrawn from the gas stream in a cooling an quenching stage where an aqueous solution is sprayed into the gas steam.
  • the product alkaline solution is cooled to below 200°C.
  • the combustible gas is used for generating steam or as a synthesis gas.
  • the steam turbine is of back pressure type preferably selected to fit the need of process steam for the mill.
  • WO 91/15665 In WO 91/15665 is described a method and apparatus for generation of electricity and steam from a pressurized black liquor gasification process. Energy is recover in a gas turbine/back pressure steam turbine system. Excess steam generated in the mill is recirculated in the gas turbine or the combustor thereof for increasi the generation of electricity. This procedure is kno to the industry as a steam injected gas turbine here ⁇ inafter referred to as STIG.
  • a bottoming steam cycle as in these inventions has an inherent high thermodynamic irreversiblity since the evaporation of water occurs at constant temperature, whereas the heat release occurs at varying temperatu ⁇ res, leading to lower thermal efficiencies.
  • the objective of the present invention is to provide process for more efficient and less capital intensive production of electric power and process steam from gasification of black liquor using a recuperated gas turbine cycle following a gas quench cooler and heat exchange system where the hot process gas from the gasifier reaction zone is cooled to a temperature bel 150 C, simultaneously recovering sensible and latent heat transferred for generation of steam for mill internal use.
  • a substantial quantity of sensible heat can also be extracted from hot liquids such as quench liquids, condensates and coolants, discharged from or within t quench zone and/or heat exchange zones.
  • Recovery of latent and sensible heat can be performed in various types of equipment including heat exchange steam generators, boiler feed water heaters and heat pumps.
  • latent and/or sensible heat in the gas and/or liquid streams is recovered using a reversed absorption heat pump, where a heat absorbing medium such as for example sodium hydroxide solution used for heat transfer.
  • a heat absorbing medium such as for example sodium hydroxide solution used for heat transfer.
  • the cooled combustible process gas is transferred to gas turbine system in which some or all of the excess air, which is used as thermal diluent and working fluid, is replaced with water vapor.
  • Gas turbines are very sensitive to contaminants in th incoming gas stream, in particular sulfur oxides and alkali salts. To prevent harmful effects on turbo machinery, the gases have to be substantially free fr these and other contaminants, in particular if the ga is used as fuel in an internally fired gas turbine cycle. It is therefore important to have efficient g cleaning in the present invention in particular with respect to sodium, as sodium is a dominant inorganic compound in cellulose waste liquors. It is appreciated that substantially all vaporized sodium compounds and particulates are removed in the quench gas cooler and scrubbing system of the present invention. Saturation vapour pressure of the harmful components in question is very low at temperatures below 200°C.
  • the process gas can be filtered or sodium compounds can be sorbed on an appropriate involatile inorganic sorbent, such as an alumino-silicate before the gas enters the gas turbine combustor.
  • an appropriate involatile inorganic sorbent such as an alumino-silicate before the gas enters the gas turbine combustor.
  • Zeolites may be used as filters or as sorbant surface for alkali removal.
  • the exhaust from the gas turbine contains a large quantity of sensible heat and if discharged to atmosphere large quantities of potentially useful energy are wasted.
  • this exhaust heat can be exploited in various ways, for example to produce stea in a heat recovery steam generator (HRSG) , which can b used for process needs directly or in a cogeneration figuration, or to produce more power in a condensing steam turbine.
  • HRSG heat recovery steam generator
  • combined gas turbine and steam turbine cycles based on heavy duty industrial turbines are not the best candidates for applications in the relatively modest scales in conjunction with black liquor gasifi ⁇ cation.
  • Yet another method to exploit the turbine exhaust is preheat the air leaving the compressor against engine exhaust in a recuperative heat exchanger and simultan ously use interstage cooling during air compression. Injection of water in a recuperative cycle can furthe improve efficiency.
  • Stack gas recirculation to use all the cycle air for combustion can be attractive in indirect cycles, mini ⁇ mizing NO emissions and lowering capital cost.
  • Fig. 1 discloses a preferred embodiment of an arrangement according to the invention
  • Fig. 2 discloses an arrangement for cogeneration of 12 steam according to the invention.
  • a cellulose waste liquor con ⁇ taining hydrocarbonaceous material and inorganic sodiu compounds is reacted with an oxygen containing gas in free flow gas generator A to produce a combustible gas
  • the gas generator operates at a reaction zone temperature of between 700-1500 C and at a pressure of 1-100 bar.
  • the hot effluent gas stream from the gas generator is rapidly cooled through direct contact with an aqueous liquid in a quench cooler 1, see figure 1.
  • the main part of the cooling is a result of evaporation of part or all of the aqueous quench liquid.
  • the temperature of the effluent gas 2 and quench liquid 3 is governed by the selected operating pressure of the gas generato and corresponds to the temperature of saturated steam at this pressure.
  • the saturated gas leaves the quench system at temperature in the range of 60-220 C and a pressure ranging from 1 to 100 bar, preferably at the same pressure as in the gas generator less pressure drop in the quench.
  • the combustible gas is then further cooled in one or more heat exchangers 4, simultaneously generating process steam 5 and/or hot water.
  • a large portion, if not all, of the mills' steam deman is thus covered by the cooling system heat exchange steam generators.
  • a downstream gas turbine system B can hence be optimized for power generation.
  • the condensate 6 resulting from the cooling which may contain sodium compounds is withdrawn from the process gas and mixed with other aqueous liquids to form green liquor 7 for use in cooking liquor preparation.
  • the process gas leaving the heat exchangers is further cooled by scrubbing B with an aqueous liquid 8, which further enhances the removal of any carryover sodium fumes.
  • the resulting clean combustible gas 9 has a temperatur of between 20 and 150°C and a pressure substantially a the same pressure as in the gas generator.
  • the gas is saturated, and water vapor partial pressure correspond to the temperature and total pressure.
  • Further gas purification and sodium removal can optio ⁇ nally be performed by downstream filtering or electro ⁇ static precipitation.
  • the heating value of the process gas is dependent on the type and amount of oxidant used in the gas genera ⁇ tor.
  • the use of air as oxidant results in that about half the product gas consists of nitrogen, thus result ing in a gas with a rather low calorific value.
  • the clean product gas from air blown black liquor gasification has a heating value, in the range of 3.5- MJ/Nm 3 .
  • the temperature of the process gas is raised by heat exchange with hot circulating green liquor and/or circulating compressor intercooling coolant 10 and/or gas turbine exhaust 11.
  • the preheated clean combustible gas is thereafter used as fuel in a gas turbine plant comprising a compressor C, combustor D and gas turbine E.
  • the mass flow through the turbine is increas ed by injecting water or steam into the gaseous stream entering the combustor or before expansion in the gas turbine and by preheating said gaseous streams by heat exchange with gas turbine exhaust.
  • recuperators F which recycle a large portio of the turbine or combustor exhaust energy to preheat compressor discharge air and/or fuel gas prior to the combustor.
  • compressor intercooling signi ⁇ ficantly improve the performance of recuperated cycles, since the compressor work is reduced and thermal energ lost by intercooling is counterbalanced by extraction of more heat from the exhaust gases in the recuperator.
  • the compressed air stream is cooled after compression by adding water 12 to the air stream in a humidification tower G, in which all or part of the injected water evaporates.
  • the dewpoint decides maximum water addition.
  • the humid compressed air is heated by hea exchange with gas turbine exhaust.
  • Maximum heat is recovered from the exhaust gas when th temperature of the air at the inlet of the recuperator is equal to the dewpoint temperature.
  • the evaporative regeneration is performed in one or more steps with humidification towers before the recuperators.
  • An alternative embodiment is to arrange an evaporative aftercooler after the compressor discharge, followed b a water injected evaporative recuperator.
  • Yet another objective of the invention is reached by providing pressurized oxidant air for the operation o the gas generator.
  • the reduced need for diluent cool ing air in the gas turbine in the present invention enables provision for supply of all the air needed fo gasification.
  • Another specific advantage of the process of the pre ⁇ sent invention is that it can utilize low level heat from the discharged flue gases 20, the compressor intercooler 13 or from the gasification process or utilize low level heat from elsewhere in the mill to preheat water used for evaporative cooling of the compressed air and/or fuel gas, and hence improve overall efficiency.
  • a major advantage of the present invention is its simplicity. The entire bottoming cycle of a combined cycle is eliminated, resulting in lower capital costs for a given electricity output. Recuperators and humidifiers does not present serious design or opera ⁇ tional difficulties.
  • a disadvantage with water or steam injected cycles is that water added to the humidifier is lost if no meth to recapture the vapor from the exhaust gas is used.
  • the water consumption for humidification is in the order of 0.1-0.8 kg water per kWh power and about twi as much for power efficient STIG systems. In both cases the water has to be processed to boiler feed water quality.
  • the gas turbine cycle in the present invention can be integrated with a facility for production of deminera lized water to be used for injection.
  • a deminer lization plant could be based on various principles known from the sea water desalination industry.
  • Demineralization plants based on distillation process are most preferred for use in the present invention since they can use heat from the exhaust stream direc ly or use surplus steam or low level heat from else ⁇ where in the mill.
  • heat pumps are used for recovery of sensibl and latent heat from the combustible gas stream and/o alkaline liquors discharged from the quench zone and/ heat exchange zone.
  • the use of heat pumps is particularly attractive when gasification pressure is lower than say 10-15 bar, as useful steam in a pressu range of 2-10 bar can be generated despite lower saturation temperature in the gas streams and lower temperature in the liquid streams discharged from the quench zone.
  • Water injection into the compressed air or the fuel ga as practised in several embodiments of the present invention lowers the adiabatic flame temperature in t combustor, however, as long as combustion is stable, this effect has negligible impact. Higher solids loading in the black liquor feed counteract this effe by increasing fuel gas heating value and adiabatic flame temperature.
  • Average water vapor partial pressure in the turbine exhaust gas stream in the present invention is in the order of 5-25 % of the total pressure.
  • a kraft market pulp mill produces 1070 ton/day bleache pulp, generating a black liquor flow of 1662 ton/day a dry solids.
  • the mill's internal steam requirements amount to 112 ton 5 bar steam and 36 ton 13 bar steam per hour. Electricity consumption in the mill is 600 kWh/ton pulp or 642 MWh/day (26.75 MW) .
  • Black liquor is fed to a suspension bed gasifier integrated with an evaporative recuperated gas turbine system for energy recovery.
  • the black liquor has the following data at the gasifie entrance:
  • the gasifier is operated at a pressure of 25 bar and a reaction zone temperature of 950 C.
  • Air is bled off from the gas turbine compressor (14) and used as oxidant in the gas generator.
  • the tempera ture and pressure of the air leaving the gas turbine compressor are increased by a booster compressor.
  • the process gas leaving the gasifier is cooled by heat exchange in two indirect heat exchangers, generating 112 ton 5 bar steam per hour and 7 ton 2 bar steam per hour for export to the mill.
  • the gas is further coole by scrubbing in a countercurrent spray scrubber.
  • the clean process gas leaving the scrubber has a tempe ⁇ rraattuurree ooff 4400°CC aanndd aa pprreessssiure of 23 bar.
  • the gas has the following composition:
  • the process gas is discharged from the gasifier/scrub ⁇ ber and used as fuel in a recuperative gas turbine plant.
  • the process gas temperature is in ⁇ creased to 130°C by heat exchange with hot water (1( from the compressor intercooler (13) and the gas is further preheated by gas turbine exhaust in a rreeccuuppeerraattiivvee hheeaatt eexxcchhaannggeer to 450 C before entering the gas turbine combustor.
  • Boiler feed water (10) is preheated in the compressor intercooler from 30 C to 145 C, and used for combustib le gas preheat and partly as injection water in the humidifier and as boiler feed water. Excess water (15) is used as bark boiler feed water. A stream of boiler feed water (18) from the gas preheater (16) is preheated by indirect heat exchange (21) with green liquor from the gasifier/scrubber circulation loop fro 125°C to 160°C.
  • the gas turbine exhaust stream is finally discharged from the gas turbine plant and recuperators through line (20) .
  • the gas turbine cycle has the following main design criteria:
  • Power consumption in air booster compressor is 3.3 MW (efficiency 0.8).
  • Process gas generated in a black liquor gasifier is cooled by heat exchange and further cooled in a scrubber to a temperature of 40°C, recovering 86 ton 5 bar steam and 27 ton 2 bar steam per hour for use in the mill.
  • a scrubber to a temperature of 40°C
  • the clean cooled process gas is preheated to 300 C in heat exchanger (24) , whereafter the process gas is humidified in a countercurrent multistage saturator, decreasing the gas temperature to 131 C.
  • the saturate process gas is thereafter preheated in a heat exchange by extracting heat from the gas turbine exhaust.
  • the temperature of the process gas entering the gas turbin combustor is 450°C.
  • Gas turbine exhaust heat is used for heat exchange wit incoming fuel gas in two recuperative heat exchangers and for generation of 34 ton 12 bar steam per hour in waste heat boiler.
  • Compressor intercooling is not used in this cycle and the heat in compressor exhaust is transferred directly to the combustor.
  • the turbine exhaust flue gas leaving the recuperators still contain a considerable amount of heat, although at a low temperature. This heat can for instance be used for low pressure steam generation. Due to the comparatively high water content in the flue gas, also condensing heat recovery can be profitable.
  • Another potential advantage of condensing flue gas hea recovery is that relatively pure water can be recovere for recirculation and use as injection water or steam.
  • the modern kraft mill often has hog and/or bark fired boilers or gasifiers integrated. Yet other mills have natural gas available for various purposes, such as lime kiln fuel.
  • the present invention can be practised in combination with combustion of other gaseous or liquid hydrocarbon fuels available at the mill.
  • a natural gas or biogas can be fired in a preburner in the compressed air stream or at the gas turbine combus tor increasing gas turbine inlet temperature and power output.
  • the same objective can be reached by blending the combustible gas from the gasifier with another hydro ⁇ carbonaceous fuel.
  • Yet another method to increase power output in the present invention is to inject steam in various locations in the combustor or gas turbine.
  • the quench cooler following the gas generator could be replaced by liquid cyclones or by liquid injection cooling.
  • such devices are grouped under the expression "contacting zone”.

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  • Engineering & Computer Science (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Engine Equipment That Uses Special Cycles (AREA)
  • Treatment Of Water By Oxidation Or Reduction (AREA)

Abstract

L'invention se rapporte à un procédé de récupération d'énergie dans un gaz combustible générée par l'oxydation partielle de liqueur de déchets de cellulose dans un générateur de gaz (A) fonctionnant dans une plage de température de 600 à 1300 °C et à une pression de 1 à 100 bar. Ledit procédé consiste à utiliser ce gaz comme carburant dans un cycle de turbine à gaz récupéré (C, E), dans lequel de l'eau et/ou de la vapeur sont injectées afin d'humidifier l'air comprimé et/ou le gaz combustible, et d'augmenter ainsi le flux massique et le débit du fluide moteur de la turbine.
PCT/SE1992/000363 1992-05-29 1992-05-29 Procede de recuperation d'energie dans un gaz combustible WO1993024703A1 (fr)

Priority Applications (14)

Application Number Priority Date Filing Date Title
CA002136817A CA2136817A1 (fr) 1992-05-29 1992-05-29 Procede de recuperation de l'energie dans un gaz combustible
JP6500439A JPH08501605A (ja) 1992-05-29 1992-05-29 可燃ガスからのエネルギの回収方法
BR9207135A BR9207135A (pt) 1992-05-29 1992-05-29 Um processo para recuperar energia de um gas combustivel
PCT/SE1992/000363 WO1993024703A1 (fr) 1992-05-29 1992-05-29 Procede de recuperation d'energie dans un gaz combustible
US08/343,555 US5507141A (en) 1992-05-29 1992-05-29 Process for recovering energy from a combustible gas
AU23210/92A AU2321092A (en) 1992-05-29 1992-05-29 A process for recovering energy from a combustible gas
EP92915554A EP0642611B1 (fr) 1992-05-29 1992-05-29 Procede de recuperation d'energie dans un gaz combustible
DE69226287T DE69226287T2 (de) 1992-05-29 1992-05-29 Verfahren zur energierückgewinnung aus einem brennbaren gas
CA002136829A CA2136829A1 (fr) 1992-05-29 1993-03-11 Procede pour la recuperation de produits chimiques et d'energie de liqueur residuaire de cellulose
PCT/SE1993/000212 WO1993024704A1 (fr) 1992-05-29 1993-03-11 Procede de recuperation de produits chimiques et d'energie dans des liqueurs de cellulose epuisees
EP93909103A EP0642612A1 (fr) 1992-05-29 1993-03-11 Procede de recuperation de produits chimiques et d'energie dans des liqueurs de cellulose epuisees
BR9306444A BR9306444A (pt) 1992-05-29 1993-03-11 Um processo para a recuperaçáo de compostos químicos e energia do licor residual da celulose
FI945602A FI945602A (fi) 1992-05-29 1994-11-28 Menetelmä energian saamiseksi talteen poltettavissa olevasta kaasusta
FI945603A FI945603A0 (fi) 1992-05-29 1994-11-28 Menetelmä kemikaalien ja energian saamiseksi talteen selluloosajäteliemestä

Applications Claiming Priority (3)

Application Number Priority Date Filing Date Title
BR9207135A BR9207135A (pt) 1992-05-29 1992-05-29 Um processo para recuperar energia de um gas combustivel
CA002136817A CA2136817A1 (fr) 1992-05-29 1992-05-29 Procede de recuperation de l'energie dans un gaz combustible
PCT/SE1992/000363 WO1993024703A1 (fr) 1992-05-29 1992-05-29 Procede de recuperation d'energie dans un gaz combustible

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PCT/SE1993/000212 WO1993024704A1 (fr) 1992-05-29 1993-03-11 Procede de recuperation de produits chimiques et d'energie dans des liqueurs de cellulose epuisees

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AU (1) AU2321092A (fr)
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Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0821135A1 (fr) * 1996-07-22 1998-01-28 N.V. Kema Production d'énergie au moyen d'un cycle combiné à gaz et au charbon
ES2154572A1 (es) * 1998-11-05 2001-04-01 Dalering Desarrollos Energetic Sistema con ciclo abierto de turbina de gas de combustion externa.
EP1193341A1 (fr) * 2000-09-29 2002-04-03 Kvaerner Pulping Oy Procédé et appareil pour la préparation de liqueur verte
EP1609958A1 (fr) * 2004-06-22 2005-12-28 Siemens Aktiengesellschaft Turbine à gaz avec compresseur et récupérateur
WO2011123034A1 (fr) * 2010-03-30 2011-10-06 Chemrec Ab Gazéification de liqueur épaisse de sulfite
JP2013502526A (ja) * 2009-08-21 2013-01-24 クロネス アーゲー バイオマスを使用する方法および装置
CN110219724A (zh) * 2019-06-10 2019-09-10 宁波大学 一种船舶尾气净化及余热回收系统和方法

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
FR2946088B1 (fr) * 2009-05-26 2015-11-20 Inst Francais Du Petrole Systeme de production d'energie, notamment electrique, avec une turbine a gaz utilisant un combustible provenant d'un gazeifieur
DE102009038322A1 (de) 2009-08-21 2011-02-24 Krones Ag Verfahren und Vorrichtung zur Umwandlung thermischer Energie aus Biomasse in mechanische Arbeit
NZ706072A (en) 2013-03-08 2018-12-21 Xyleco Inc Equipment protecting enclosures

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US4682985A (en) * 1983-04-21 1987-07-28 Rockwell International Corporation Gasification of black liquor
US4753068A (en) * 1987-01-15 1988-06-28 El Masri Maher A Gas turbine cycle incorporating simultaneous, parallel, dual-mode heat recovery
WO1991015665A1 (fr) * 1990-04-03 1991-10-17 A. Ahlstrom Corporation Procede et appareil servant a produire de la chaleur et de l'electricite dans un malaxeur de pate au sulfate

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US4492085A (en) * 1982-08-09 1985-01-08 General Electric Company Gas turbine power plant

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4682985A (en) * 1983-04-21 1987-07-28 Rockwell International Corporation Gasification of black liquor
US4753068A (en) * 1987-01-15 1988-06-28 El Masri Maher A Gas turbine cycle incorporating simultaneous, parallel, dual-mode heat recovery
WO1991015665A1 (fr) * 1990-04-03 1991-10-17 A. Ahlstrom Corporation Procede et appareil servant a produire de la chaleur et de l'electricite dans un malaxeur de pate au sulfate

Cited By (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0821135A1 (fr) * 1996-07-22 1998-01-28 N.V. Kema Production d'énergie au moyen d'un cycle combiné à gaz et au charbon
ES2154572A1 (es) * 1998-11-05 2001-04-01 Dalering Desarrollos Energetic Sistema con ciclo abierto de turbina de gas de combustion externa.
EP1193341A1 (fr) * 2000-09-29 2002-04-03 Kvaerner Pulping Oy Procédé et appareil pour la préparation de liqueur verte
EP1609958A1 (fr) * 2004-06-22 2005-12-28 Siemens Aktiengesellschaft Turbine à gaz avec compresseur et récupérateur
JP2013502526A (ja) * 2009-08-21 2013-01-24 クロネス アーゲー バイオマスを使用する方法および装置
WO2011123034A1 (fr) * 2010-03-30 2011-10-06 Chemrec Ab Gazéification de liqueur épaisse de sulfite
CN102884248A (zh) * 2010-03-30 2013-01-16 坎雷克股份公司 亚硫酸盐稠液的气化
CN110219724A (zh) * 2019-06-10 2019-09-10 宁波大学 一种船舶尾气净化及余热回收系统和方法

Also Published As

Publication number Publication date
CA2136829A1 (fr) 1993-11-30
FI945603A (fi) 1994-11-28
FI945603A0 (fi) 1994-11-28
AU2321092A (en) 1993-12-30
BR9207135A (pt) 1996-11-19
EP0642612A1 (fr) 1995-03-15
WO1993024704A1 (fr) 1993-12-09

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