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WO2012095243A1 - Installation de turbine gaz/vapeur pour raccordement à l'énergie solaire - Google Patents

Installation de turbine gaz/vapeur pour raccordement à l'énergie solaire Download PDF

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Publication number
WO2012095243A1
WO2012095243A1 PCT/EP2011/073376 EP2011073376W WO2012095243A1 WO 2012095243 A1 WO2012095243 A1 WO 2012095243A1 EP 2011073376 W EP2011073376 W EP 2011073376W WO 2012095243 A1 WO2012095243 A1 WO 2012095243A1
Authority
WO
WIPO (PCT)
Prior art keywords
turbine plant
heat exchanger
steam turbine
gas
steam
Prior art date
Application number
PCT/EP2011/073376
Other languages
German (de)
English (en)
Inventor
Martin Hadlauer
Original Assignee
Martin Hadlauer
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 Martin Hadlauer filed Critical Martin Hadlauer
Priority to EP11802082.5A priority Critical patent/EP2663755A1/fr
Publication of WO2012095243A1 publication Critical patent/WO2012095243A1/fr

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Classifications

    • 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
    • F02C6/00—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use
    • F02C6/18—Plural gas-turbine plants; Combinations of gas-turbine plants with other apparatus; Adaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
    • 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
    • F01K23/10—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 with exhaust fluid of one cycle heating the fluid in another cycle
    • 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
    • F02C1/05—Gas-turbine plants characterised by the use of hot gases or unheated pressurised gases, as the working fluid the working fluid being heated indirectly characterised by the type or source of heat, e.g. using nuclear or solar energy
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03G—SPRING, WEIGHT, INERTIA OR LIKE MOTORS; MECHANICAL-POWER PRODUCING DEVICES OR MECHANISMS, NOT OTHERWISE PROVIDED FOR OR USING ENERGY SOURCES NOT OTHERWISE PROVIDED FOR
    • F03G6/00—Devices for producing mechanical power from solar energy
    • F03G6/003—Devices for producing mechanical power from solar energy having a Rankine cycle
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F22—STEAM GENERATION
    • F22B—METHODS OF STEAM GENERATION; STEAM BOILERS
    • F22B1/00—Methods of steam generation characterised by form of heating method
    • F22B1/006—Methods of steam generation characterised by form of heating method using solar heat
    • 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
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/40—Solar thermal energy, e.g. solar towers
    • Y02E10/46—Conversion of thermal power into mechanical power, e.g. Rankine, Stirling or solar thermal engines
    • 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
    • Y02E50/00—Technologies for the production of fuel of non-fossil origin
    • Y02E50/10—Biofuels, e.g. bio-diesel

Definitions

  • the present invention relates to a gas turbine plant, in particular a coupled gas / steam turbine plant.
  • An object of the invention may be to provide a gas turbine plant, in particular a coupled gas / steam turbine plant, which allows improved control.
  • a goal of specific embodiments of the invention may be, on the one hand, a coupled combined cycle gas turbine plant
  • a gas turbine plant has a first heat exchanger, which can be coupled into a secondary flow of an expansion stage, in particular a main turbine stage, and a second heat exchanger, wherein the first heat exchanger is connected to the second heat exchanger
  • Heat exchanger is connected in series in the secondary flow and so is set up that it performs a steam overheating and wherein the second heat exchanger is arranged such that by means of it evaporation and / or preheating, in particular a fluid, is feasible.
  • the second heat exchanger may be configured such that it is flowed through by a condensate on the secondary side.
  • this condensate may be introduced into an evaporation tank of a steam turbine plant, which together with the gas turbine plant can form a coupled gas / steam turbine plant.
  • the heat exchangers can also be used as
  • Gas / steam turbine plant created which has a gas turbine plant according to an exemplary aspect and a steam turbine plant.
  • the steam turbine plant may be energetically coupled to the gas turbine plant by means of the first and the second heat exchanger.
  • this may also constitute a coupling between the gas turbine plant and the steam turbine plant.
  • all parts or elements of the combined cycle gas turbine plant that serve to generate, pass or utilize gas or flue gas may be considered part of a gas turbine cycle.
  • all parts or elements which serve the production, forwarding or use of steam can be attributed to a steam cycle of the steam turbine plant, which together with the Gasurbinenanlange the
  • a connection or coupling of the two circuits may be performed by heat exchangers, which are thus associated with both the gas turbine cycle and the steam turbine cycle.
  • heat exchangers which are thus associated with both the gas turbine cycle and the steam turbine cycle.
  • Notification is to include not only water vapor, but any gaseous form of a liquid at ambient temperature fluid.
  • This secondary turbine may be coupled to an output of the first heat exchanger such that it can be operated with the superheated steam by means of the first heat exchanger.
  • the output may be an output of the secondary side of the first heat exchanger.
  • the further expansion stage superheated steam of the first heat exchanger may be supplied.
  • the superheated steam of the first heat exchanger exclusively on the further expansion stage, for.
  • Gas turbine plant to a third heat exchanger which is adapted such that it can be coupled into the main flow of the expansion stage and is further adapted such that it also performs a steam overheating.
  • the third one may
  • the third heat exchanger may thus be set up in such a way that by means of it alternatively or in addition to the further expansion stage or the secondary turbine superheated steam or hot steam is supplied.
  • Gas turbine plant on a burner which is upstream of the expansion stage.
  • flue gas may be generated, which can be supplied to the expansion stage.
  • the air flow before entering the burner may in this case be preheated via a heat exchanger, which is flowed through by the primary flow of the gas turbine plant on the primary side.
  • Gas turbine plant further comprises a combustion device, which is connected in the main stream after the expansion stage, wherein the combustion device is arranged such that flue gas of the combustion device on the primary side through a heat exchanger for heating compressed air can be conducted .
  • the heat exchanger for air heating is now with the flue gas stream from this
  • the second heat exchanger is designed for preheating condensate, which is then brought into a container for flash evaporation.
  • the third is
  • Heat exchanger configured for preheating of condensate, which is then placed in a container for flash evaporation.
  • the third is
  • the coupled gas / steam turbine plant may be set up such that the preheated condensate is brought to flash evaporation in a tank.
  • the third heat exchanger and / or the first heat exchanger are configured such that superheated steam can be supplied by means of this or this further expansion stage of the steam turbine plant.
  • the second heat exchanger and / or the third heat exchanger are configured for condensate preheating and the first heat exchanger for steam superheating.
  • the steam turbine plant has a
  • Solar collector which is set up so that by means of it heat for evaporation or preheating in a working fluid circuit of the steam turbine plant can be introduced.
  • a plurality of solar collectors may be provided.
  • the coupled According to an exemplary embodiment of the coupled
  • the solar collector is set up for the preheating of condensate.
  • some or all of the solar collectors may be designed for the preheating of condensate.
  • the condensate may be stored in a container or collecting container or be introduced into the container for flash evaporation.
  • the steam turbine plant further comprises a distributor and a circulation pump, wherein the
  • the distribution device may comprise or be a valve or a valve system.
  • the circulation pump may be connected in a condensate circuit, which serves to distribute the condensate.
  • the steam turbine plant further comprises a further distribution device and a container, wherein the
  • the second heat exchanger is set up such that it is switched off when the solar collector is switched on and / or bypassed via a bypass.
  • a control which is set up such that the secondary side of the second heat exchanger is not flowed through by a working fluid. This may be done, for example, by controlling valves and / or pumps / compressors which move the working fluid through the working fluid circuit.
  • the steam turbine plant or the steam turbine cycle has a main expansion stage or main turbine, which to the secondary side of the first and / or third
  • Heat exchanger is coupled.
  • the steam turbine plant or the steam turbine cycle has a secondary expansion stage or secondary turbine.
  • the secondary expansion stage and the secondary turbine have a secondary expansion stage or secondary turbine.
  • the steam turbine plant has a
  • the coupled gas / steam turbine plant may be arranged such that the fuel is subsequently introduced into a combustion device of the
  • Gas turbine plant can be introduced.
  • the above object may be achieved by providing a gas turbine plant, in particular a coupled gas / steam turbine plant, in which the air flow after exiting the first or even single (depending on
  • Gas turbine plant is divided into a main and a secondary flow. According to this exemplary aspect, two are in the side stream
  • Heat exchanger which can be designed depending on the system configuration as a direct evaporator, condensation heater or steam superheater, switched. According to this exemplary aspect is also in operation without
  • the secondary flow may optionally be introduced via a bypass into the flue gas stream after exiting the heat exchanger for air heating.
  • the now "dilute" flue gas is then passed through an end expansion stage of the gas turbine plant
  • the two mass flows can optionally be merged, which may be advantageous if another heat exchanger is provided for cogeneration for a heating network of the
  • the heat extraction according to the invention for the steam turbine process can be advantageously used for two types of plant, - a single-stage
  • Gas turbine plant with downstream combustion device or burner with air heater and a two-stage gas turbine plant with interposed combustion device or burner with
  • Heat exchanger designs in the main and secondary flow may now provide the opportunity to design these systems for high, medium or low solar support.
  • Solar load fluctuations can be compensated over a wide range and also in the base load (no solar heating), a good efficiency can be achieved, although preferably inferior fuels with
  • Ash production (biomass, coal) should be used.
  • Incinerator be enabled. Such an exemplary gas turbine plant may allow the daytime
  • Temperatures refer to systems with a given turbine inlet temperature of 900 ° C and a
  • FIG. 1 shows a single-stage gas turbine plant for the combustion of biomass with a compressor unit, an expansion stage in the air flow, a downstream combustion device and a heat exchanger for air heating. Coupled is a steam circuit with a
  • Fig. 2 is a schematic representation of the same type of investment as in Fig l with the modification that the steam generation is not directly in
  • Heat exchanger takes place, but via a flash evaporation in the steam tank.
  • Fig. 3 is a schematic representation of the system of Fig. 2, extended by advantageous connection possibilities for feeding heat networks.
  • Fig. 4 is a schematic representation of the plant of Fig. 2, extends a second steam turbine set. The plant falls into the category: • single-stage gas turbine;
  • FIG. 5 is a schematic representation of the system of Fig. 4, extended by advantageous connection possibilities for feeding heat networks.
  • Fig. 6 is a schematic representation of a system which, in contrast to the system shown in Fig. 4 in the main stream provides a heat exchanger, which is no longer for the evaporation of preheated
  • Condensate is designed, but is designed as a steam superheater.
  • the plant falls into the category:
  • Fig. 7 is a schematic representation of the system of Fig. 6, extended by advantageous connection possibilities for feeding heat networks.
  • 8 shows a two-stage gas turbine plant for combustion of biomass with a two-stage compressor unit, a main expansion stage in the air flow and an end expansion stage in the flue gas flow, one connected between the two expansion stages
  • Incinerator and a heat exchanger for air heating Coupled is a steam cycle with two steam turbine sets and.
  • the plant falls into the category:
  • FIG. 9 is a schematic representation of the system of Fig. 8, extended by advantageous connection possibilities for feeding heat networks.
  • Fig. 10 is a schematic representation of a system which, in contrast to the system shown in Fig. 8 in the main stream provides a heat exchanger, which is no longer designed for steam superheating, but is designed as a condensate heater for the evaporation process.
  • the plant falls into the category:
  • Fig. 11 is a schematic representation of the system of Fig. 10, extended by advantageous connection possibilities for feeding heat networks
  • Fig. 12 shows how short-term load fluctuations from the solar circuit via a small buffer memory can be compensated to the extent that the incinerator has time to suddenly changed conditions to regulate the correct power, or as short times (10 - 15 minutes in case of sudden cloud cover) without Solar energy can be bridged without the load situation at the
  • FIG. 1 shows a single-stage gas turbine plant for the combustion of biomass 38 with a compressor unit 1, an expansion stage 4 in the air flow, a downstream combustion device 3 and a heat exchanger 13 for air heating. Coupled is a steam cycle with a steam turbine set 15, a device for steam condensation 16, thermal solar collectors 17 and a container for
  • Vacuum evaporation 18 The air flow after exiting the
  • Expansion stage 4 is branched into two sub-streams.
  • the distribution of the mass flows between main and secondary flow takes place, for example, approximately in the ratio of 70% to 30%.
  • a heat exchanger 7 for condensate evaporation is arranged in the main flow, and two heat exchangers 8 and 9 connected in series flow for steam superheating (8) up to the turbine inlet temperature or the condensate heating (9) up to the evaporation temperature.
  • the steam turbine is always operated at a constant and thus optimal load.
  • Heat exchangers 7, 17 Cold exchangers 7, 17 (Collectors are used as heat exchangers
  • the heat removal via the heat exchanger 7 may, for. B. be controlled via a bypass connection of the main stream (not shown here).
  • a Kondensatrochrikpumpe 20 and a Kondensatumskylzpumpe 19 can solar energy independent, purely to the predetermined
  • Process parameters such as steam quantity, condensation and
  • the circulation pump 21 for the collectors can also be operated at a constant flow rate.
  • the collectors reach at a given return temperature of 185 ° C in the
  • Top performance for example, a flow temperature of 200 ° C, - at 2/3 of the peak load 195 ° C.
  • the pressure drops to the vapor pressure of 185 ° C ( ⁇ 10 bar) and saturated vapor separates quantitatively in proportion to the temperature drop.
  • Incinerator 3 increases less with less heating at mass and thus can be further cooled in the heat exchanger 13. The exhaust gas temperature drops and thus the efficiency of the
  • Heat exchanger 8 and 9 are not in the flue gas stream but in pure air flow can be a cooling to near the
  • Heat capacity of the steam to be overheated is about half as high as the heat capacity of the condensate is through the series-connected heat exchanger 8 and 9 given an ideal temperature spread, so that the air in the bypass flow at a condensate return temperature of 50 ° C can be cooled to 100 ° C.
  • the two pumps 19 and 20 ideally provide the same
  • Condensate and basically it is possible to provide a single pump that directs the condensate directly into the heat exchanger 9, without a connection to the steam tank 18 is.
  • a further combustion device 32 is preferably provided for combustion of high-quality fuels without ash formation in front of the expansion stage 4. This also applies to all the further plants from FIGS.
  • Fig. 2 shows a schematic representation of the same investment type as in Fig. L with the modification that the steam generation does not take place directly in the heat exchanger 7, but via a flash evaporation in the steam tank 18.
  • Condensate is heated slightly (5 -15 °) above the saturated steam temperature in the steam tank 18. In order to obtain no evaporation in the heat exchanger 7 and in the collectors, the heated condensate via a throttle, which builds up a corresponding back pressure in the
  • Fig. 3 shows a schematic representation of the system of Fig. 2, extended by advantageous connection possibilities for feeding heat networks.
  • the flue gas stream after exiting the air heater 13 still has a temperature of about 200 ° C. This can still be cooled to 100 ° C without condensation occurs.
  • a heat exchanger 27 can be provided for heat input into a heating network, - an additional heating of the system is not necessary. Another common option is to use the heat from the
  • Heat extraction at back pressure (vapor pressure at 75 -100 °) are to be provided.
  • the expanded steam is passed through a heat exchanger 28, is traversed by heating medium, recondensed.
  • By decoupling at back pressure the electrical power of the system decreases.
  • Another interesting option is to use the
  • Circulation pump 21 and heat exchanger 7 are already anyway
  • the heating power in the combustion device 3 must be increased accordingly. Another possibility is to decouple heat directly from the solar circuit.
  • the solar heat is through a separate circulation circuit with its own pump 26 via the
  • Heat exchanger 26 is fed into the heating circuit.
  • the solar circuit can be completely switched off from the evaporation process of the system.
  • the temperature in the solar circuit may be below the process temperature for evaporation (185 ° C) and adjusted to the return temperature of the heating medium.
  • Fig. 4 shows a schematic representation of the plant of Fig. 2, extended by a second steam turbine set. This facility can now be designed according to that in the base load only the small steam turbine 14 is in operation.
  • the steam turbine process is heated via the heat extractors 8 and 9 in the secondary flow.
  • Heat exchanger 8 is designed for overheating of the steam.
  • Heat exchanger 9 takes over the heat content for the
  • Condensate heating and evaporation In contrast to the function in FIG. 2, not only is the condensate which returns via the high-pressure pump 20 forwarded, but additional condensate from the steam container 18 is admixed.
  • the condensate is heated slightly (5 -15 °) above the saturated steam temperature in the steam tank 18.
  • the heated condensate is returned via a throttle, which builds up a corresponding back pressure in the steam tank 18.
  • the large steam turbine 15 is put into operation, - the small steam turbine is ideally switched off, since the efficiency of this turbine is lower. Now there are two possibilities for the sizing of the steam turbine 15.
  • Heat exchanger 9 now assumes only the function of the condensation heating in the solar operation up to the evaporation temperature.
  • the performance of heat exchanger 8 increases approximately by the amount needed in the base load for the evaporative energy. Since the steam superheating takes place exclusively via this heat exchanger and the heat output of the two heat exchangers 8 and 9 is fixed in the secondary flow of the gas turbine plant, the sizing of the turbine 15 is also fixed. Due to the serial connection of the
  • Heat capacity of water The necessary heat for the evaporation can be distributed over the collectors 17 and / or the heat exchanger 7 are introduced in the main flow of the gas turbine.
  • Heat exchanger 7 to be inactive. In this sense, this plant falls under the category "medium solar support”.
  • Heat exchanger 9 is inactive in solar operation. The performance of
  • Heat exchanger 8 increases to the maximum extractable heat in the secondary flow. Since the steam overheating exclusively on the
  • Heat exchanger 8 takes place, the size of the turbine 15 is also set.
  • the necessary heat for the evaporation and also condensate heating can now be distributed over the collectors 17 and / or the heat exchanger 7 are introduced in the main stream of the gas turbine.
  • not enough heat can be extracted via the main flow to the steam turbine process to keep constant operation.
  • solar energy fluctuation of 35% to 100% can be compensated by the additional heating to obtain a constant steam turbine operation. In times without solar energy (base load) is thus
  • Saturated steam temperature ie a maximum of 200 ° C
  • the accountable for the collectors efficiency is slightly lower than the system with turbine design on reduced solar power.
  • Fig. 5 shows a schematic representation of the system of Fig. 4, extended by advantageous connection possibilities for feeding heat networks.
  • the flue gas stream after exiting the air heater 13 still has a temperature of about 200 ° C. This can still be cooled to 100 ° C without condensation occurs.
  • Secondary flow also has a temperature of about 200 ° C in the base load.
  • Heat extraction is an additional heating of the system is not necessary. Further heat extraction is possible via the heat exchangers 25, 26, and 28. Details about the investment behavior are in the
  • Condensate removed the circulating pump 21, provided.
  • Fig. 6 shows a schematic representation of a plant, the in
  • the small turbine 14 is
  • heat exchanger 9 is inactive (circulating pump 19 does not supply condensate).
  • the heat requirement for the condensation heating and evaporation is completely covered by the collector heat.
  • the condensate circulation pump 19 becomes active.
  • the steam supply to heat exchanger 8 is over the
  • Control device or distributor 39 reduced and heat exchanger 9 compensates for the reduced power from the collector circuit.
  • the reduced performance of heat exchanger 8 for steam overheating will now turn of heat exchanger 7 in the main stream, now more Steam is supplied, balanced. This can now go so far, until the heat exchanger 8 is inactive (lock the steam supply) and
  • Heat exchanger 9 takes the maximum heat from the secondary flow. In this way, solar load waste can be compensated up to 35%. Of course, the additional heat removal from the main stream requires additional heating in the downstream
  • the main flow is cooled to near the temperature of the saturated steam to take place.
  • the main current is cooled at about 350 ° C at solar peak load, - at 35% load drop of the solar collectors up to 200 ° C.
  • This is to be considered exactly in the sizing of the steam turbine 15 and the power design of the collectors 17.
  • the system delivers about 4.5 to 5 times the power (large steam turbine 15 is active) compared to the base load in which the small steam turbine 14 is active.
  • a system with 1 MW EL power in the base load can collectors with a solar peak power of 10 to 11 MW
  • Fig. 7 shows a schematic representation of the system of Fig. 6, extended by advantageous connection possibilities for feeding heat networks.
  • the heat exchanger 7 After the heat extraction via the heat exchanger 7 is inactive in the base load as in the system in Fig. 5, exactly the same operating behavior as in Fig. 5 is given in this load case.
  • the arrangement of the heat exchanger 26, 27, 28, designed for the heat extraction in a heating network identical.
  • a heat exchanger 31 is switched directly into the main stream.
  • Fig. 8 shows a two-stage gas turbine plant for combustion of biomass 38 with a two-stage compressor unit 1 and 2, a main expansion stage 4 in the air flow and a final expansion stage 5 in the flue gas stream, one between the two expansion stages
  • Heat exchanger 13 for air heating Coupled is a steam cycle with two steam turbine sets 14 and 15.
  • the following gas turbine plant may use low grade, high ash forming fuels (e.g., humid wood) over one
  • Main turbine stages 4 downstream combustion device 3 are fired. For starting the system and for fine control of the turbine inlet temperature is an additional upstream
  • Combustion chamber 32 fueled with high quality fuels (oil, gas), provided.
  • high quality fuels oil, gas
  • the plant can be operated in almost any mixed state of high and low grade fuels.
  • the damp wood is placed in a charged container 12 for drying and preheating. After one
  • Compressor 2 initiated. Since it excretes steam during the washing process, a water reservoir 29 has water in the
  • the highly compressed air is now brought to high temperature in the heat exchanger 13 for air heating.
  • the gas stream (in the case of an inactive combustor 32, a pure air stream) after leaving the main turbine stage 4 is preferably branched into two partial streams.
  • the main stream is passed to the combustion device 3, -
  • the secondary stream is introduced to the cooled flue gas stream after exiting the heat exchanger or air heater 13.
  • the flue gas from the main burner 3 passes through the primary side of the Air heater 13 and further, after admixture of the secondary stream 6, the Endxpansionshave. 5
  • Heat exchanger 9 can be switched off completely at solar peak load. It is conceivable to provide a by-pass bypass for this purpose. The heat extraction from the main stream is always necessarily connected to an additional heating of the gas turbine plant. According to the same criteria as in the appendix to Fig. 7 this plant falls into the category "high solar support”.
  • Fig. 9 shows a schematic representation of the system of Fig. 8, extended by advantageous connection possibilities for feeding heat networks.
  • the heat extractors 31, 28 and 26 are made according to the same criteria as in the system in Fig. 7.
  • the heat extraction 27 as in the system of Fig. 7 falls away, otherwise the temperature in the final expansion stage 5 among the
  • FIG. 10 shows a schematic representation of a plant, the in
  • Evaporation process is designed.
  • the load is controlled via the three heat exchangers 7, 8, 9 according to the same scheme as in the system of FIG. 4. Due to the two load stages (large or small steam turbine active) this system also falls into the category "average solar Again, there is the possibility to design the plant for "reduced solar input” or “maximum solar input” as stated in the description of the plant in figure 4.
  • Figure 11 shows a schematic representation of the plant of figure 10, The heat decoupling 25, 26, 28 are made according to the same criteria as in the plant in Fig. 5.
  • Fig. 12 shows how short-term load fluctuations from the solar circuit can be compensated via a small buffer memory, so that the combustion device 3 suddenly changed
  • Conditions corresponding to time has to regulate the correct performance, or how short times (10 - 15 minutes in case of sudden cloud cover or changing cloud cover) can be bridged without solar energy, without the load situation at the main turbine 15 has to be changed.
  • This is achieved by providing a buffer 36 which is fed with high-energy condensate at times of high solar energy.
  • a small partial flow from the circulation of the collectors via the distribution device 33 and 37 is loaded from above into the memory 36.
  • the colder condensate from the lower region of the memory 36 is the distributor means 35 the
  • Condensate stream after the condensate pump 20 admixed In the case of solar failure, conversely, the buffer circuit is blocked via the distribution device 33, and the recirculation flow is fed into the buffer 36 from below via the distributor devices 34 and 35.
  • the distribution device 37 now opens the way for the upper
  • the memory 36 should be designed in about 10 to 15 m 3 volume. This memory can also be used for decoupling into a heat network.
  • This memory can also be used for decoupling into a heat network.
  • Temperatures in the tank (180 - 200 ° C) can be traversed at return temperatures of around 50 ° C up to 150 ° C.
  • Storage volume of assumed 10 m 3 has an energy reserve of at least 6000 MJ, - this corresponds to 1740 kWh.
  • Gas turbine Compressors are provided with screw compressors. Turbines are planned for the expansion stages. In the following simulation, a turbine inlet temperature of 900 ° C is used. The heat exchanger for air heating must be designed for a maximum temperature of 1150 ° C. The plant will
  • Gas turbine Compressors are provided with screw compressors. Turbines are planned for the expansion stages. In the following simulation, a turbine inlet temperature of 900 ° C is used. The heat exchanger for air heating must be designed for a maximum temperature of 1150 ° C. The plant will
  • Biomass combustion based on the dry mass an efficiency of over 35%.

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  • Engine Equipment That Uses Special Cycles (AREA)

Abstract

Selon un aspect cité à titre d'exemple de la présente invention, une installation de turbine à gaz présente un premier échangeur de chaleur qui peut être installé dans un flux secondaire d'un étage de détente, notamment d'un étage de turbine principal, et un deuxième échangeur de chaleur. Le premier échangeur de chaleur est monté en amont du deuxième échangeur de chaleur et est conçu pour surchauffer la vapeur pour un cycle de turbine à vapeur associé. Le deuxième échangeur de chaleur est conçu pour effectuer une évaporation et/ou un préchauffage, notamment d'un fluide.
PCT/EP2011/073376 2011-01-12 2011-12-20 Installation de turbine gaz/vapeur pour raccordement à l'énergie solaire WO2012095243A1 (fr)

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EP11150770 2011-01-12

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Cited By (5)

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WO2016147210A1 (fr) * 2015-03-13 2016-09-22 Cristaldi, Angelo Installation automatique et procédé de production d'énergie électrique à partir du rayonnement solaire, à partir d'une installation auxiliaire de type à carburant et à partir d'un système de stockage d'énergie thermique
CN109869208A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 蒸汽发电系统及使用该蒸汽发电系统的海水淡化系统
CN109867312A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 一种利用清洁能源进行海水淡化的方法及系统
CN109867313A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 一种蒸汽发电海水淡化系统
CN109970119A (zh) * 2017-12-28 2019-07-05 平高集团有限公司 一种清洁能源储能蓄能与海水淡化联产系统及方法

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DE3506102A1 (de) * 1985-02-19 1986-08-21 Mitsubishi Jukogyo K.K., Tokio/Tokyo Kohlebefeuerte energieanlage
US5727379A (en) * 1996-05-31 1998-03-17 Electric Power Research Institute Hybid solar and fuel fired electrical generating system
EP1022440A2 (fr) * 1999-01-25 2000-07-26 Siemens Aktiengesellschaft Installation de turbines à vapeur
DE60312239T2 (de) * 2002-01-24 2007-11-22 Mitsubishi Heavy Industries, Ltd. Kombikraftwerk und Verfahren zu dessen Betrieb
EP2058515A1 (fr) * 2006-08-10 2009-05-13 Kawasaki Jukogyo Kabushiki Kaisha Installation de production d'énergie par chaleur solaire et installation d'alimentation de véhicule thermique
WO2010081656A2 (fr) 2009-01-15 2010-07-22 Martin Hadlauer Turbine combinée à gaz et à vapeur

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* Cited by examiner, † Cited by third party
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DE1228108B (de) * 1962-12-28 1966-11-03 Soc D Forges Et Ateliers Du Cr Verbund-Krafterzeugungsanlage mit einer Dampf- und zumindest einer Gasturbine fuer die Leistungslieferung
DE3506102A1 (de) * 1985-02-19 1986-08-21 Mitsubishi Jukogyo K.K., Tokio/Tokyo Kohlebefeuerte energieanlage
US5727379A (en) * 1996-05-31 1998-03-17 Electric Power Research Institute Hybid solar and fuel fired electrical generating system
EP1022440A2 (fr) * 1999-01-25 2000-07-26 Siemens Aktiengesellschaft Installation de turbines à vapeur
DE60312239T2 (de) * 2002-01-24 2007-11-22 Mitsubishi Heavy Industries, Ltd. Kombikraftwerk und Verfahren zu dessen Betrieb
EP2058515A1 (fr) * 2006-08-10 2009-05-13 Kawasaki Jukogyo Kabushiki Kaisha Installation de production d'énergie par chaleur solaire et installation d'alimentation de véhicule thermique
WO2010081656A2 (fr) 2009-01-15 2010-07-22 Martin Hadlauer Turbine combinée à gaz et à vapeur

Cited By (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2016147210A1 (fr) * 2015-03-13 2016-09-22 Cristaldi, Angelo Installation automatique et procédé de production d'énergie électrique à partir du rayonnement solaire, à partir d'une installation auxiliaire de type à carburant et à partir d'un système de stockage d'énergie thermique
CN109869208A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 蒸汽发电系统及使用该蒸汽发电系统的海水淡化系统
CN109867312A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 一种利用清洁能源进行海水淡化的方法及系统
CN109867313A (zh) * 2017-12-05 2019-06-11 平高集团有限公司 一种蒸汽发电海水淡化系统
CN109867313B (zh) * 2017-12-05 2021-12-14 平高集团有限公司 一种蒸汽发电海水淡化系统
CN109970119A (zh) * 2017-12-28 2019-07-05 平高集团有限公司 一种清洁能源储能蓄能与海水淡化联产系统及方法
CN109970119B (zh) * 2017-12-28 2022-04-15 平高集团有限公司 一种清洁能源储能蓄能与海水淡化联产系统及方法

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