EP0249255B1 - Kombinierter Gas-/Dampfturbinen-Prozess - Google Patents

Kombinierter Gas-/Dampfturbinen-Prozess Download PDF

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Publication number
EP0249255B1
EP0249255B1 EP87200488A EP87200488A EP0249255B1 EP 0249255 B1 EP0249255 B1 EP 0249255B1 EP 87200488 A EP87200488 A EP 87200488A EP 87200488 A EP87200488 A EP 87200488A EP 0249255 B1 EP0249255 B1 EP 0249255B1
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EP
European Patent Office
Prior art keywords
gas
gas turbine
combustion
gasification
steam
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Expired
Application number
EP87200488A
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German (de)
English (en)
French (fr)
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EP0249255A1 (de
Inventor
Lothar Dr. Reh
Rolf Dr. Graf
Martin Hirsch
Ludolf Dr. Plass
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GEA Group AG
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Metallgesellschaft AG
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Application filed by Metallgesellschaft AG filed Critical Metallgesellschaft AG
Priority to AT87200488T priority Critical patent/ATE40182T1/de
Publication of EP0249255A1 publication Critical patent/EP0249255A1/de
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    • 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
    • F01K23/061—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 combustion in a fluidised bed
    • F01K23/062—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 combustion in a fluidised bed the combustion bed being pressurised

Definitions

  • the invention relates to a method for operating a combined gas / steam turbine process, in which the gas turbine process is operated by means of a fuel gas obtained from solid carbon-containing material and then desulfurized, and the steam turbine process is operated by means of the steam obtained during the combustion of the carbon-containing gasification residue and in which the combustion of the carbon-containing gasification residue with oxygen-containing exhaust gases from the gas turbine process takes place.
  • the above-mentioned improvement in efficiency can be achieved on the basis of thermodynamic considerations, in particular in the case of combined gas / steam turbine processes.
  • the gas turbines can in principle be gas or oil-fired, but the decisive advantage is only achieved when the gas turbine is operated with gas obtained from partial gasification of solid fuel.
  • coal is supplied to a gasification plant for partial gasification, the gas is freed of pollutants with the aid of a scrubber and then burned in the gas turbine.
  • the coke remaining in the partial gasification is burned in the furnace of a steam generator with the oxygen-containing exhaust gases from the gas turbine and the steam is fed to a steam turbine (K. Weinzierl, "Coal gasification to improve efficiency in the power plant", VGB-Krafttechnikstechnik 62 [1982], No. 5, pages) 365 ff., And Issue 10, pages 852 ff.).
  • the aforementioned configuration of the gasification stage is associated with a shift of energy from the gas turbine branch into the steam turbine branch, as a result of which - as can be determined thermodynamically - at least a substantial part of the improvement in efficiency is consumed.
  • the object of the invention is to provide a combined gas / steam turbine process which does not have the disadvantages of the known, in particular the aforementioned, process (s) and which combusts solid carbon-containing fuels in an environmentally friendly manner with a high degree of fuel efficiency and electricity generation with a high degree of efficiency enables.
  • the object is achieved by designing the method of the type mentioned at the outset in accordance with the invention in such a way that the fuel gas is circulated in a fluidized bed by gasification of 70 to 95% by weight of the carbon content in the carbon-containing material at a temperature of 900 to 1100 ° C generated, freed from pollutants in the suspension state at 850 to 950 ° C with calcium hydroxide, calcium oxide and / or calcium carbonate-containing solid and predominantly burned to a gas containing at least 5% by volume of oxygen of at least 1000 ° C for the operation of the gas turbine, the combustion of the carbon-containing gasification residue with the production of process steam in a further circulating fluidized bed at a temperature of 800 to 950 ° C. is carried out in a near-stoichiometric manner with at least 2 partial streams of oxygen-containing gases supplied at different levels, the majority of which are formed from the gas turbine exhaust gas.
  • this concept pursues the goal of using different forms of energy, e.g. as steam for heating purposes, in the form of other high-temperature heat and in the form of clean fuel gases, the combustion of which does not adversely affect product quality.
  • the degree of conversion of the primary energy (e.g. coal) into the secondary energies fuel gas and process heat should be variable within a wide range in line with the respective existing need for one or the other secondary energy.
  • solid carbon-containing material means solid fuel at ambient temperature.
  • Such materials are, for example, all types of coal including washing piles, coke, petroleum coke, wood waste, peat, oil shale, asphaltenes and refinery residues.
  • the principle of the circulating fluidized bed used in the gasification and combustion stage is characterized by the fact that - in contrast to the «classic» fluidized bed, in which a dense phase is separated from the gas space above by a clear density jump - distribution states exist without a defined boundary layer . A leap in density between the dense phase and the dust space above it does not exist; however, the solids concentration within the reactor decreases continuously from bottom to top.
  • the desulfurization of the gas produced can take place in any suspension state, e.g. in a pneumatic conveyor or in a Venturi fluidized bed with solids discharge in a downstream separator.
  • a circulating fluidized bed can also advantageously be used for desulfurization.
  • the gasification process can be carried out below 1000 ° C, e.g. Because fuel gases with a comparatively low calorific value are permissible for the operation of the gas turbine, the desulfurization can also take place in the gasification reactor itself, that is to say in situ.
  • the gasification stage can be carried out under any pressure deemed appropriate. It will usually result from the operating data of the gas turbine and will be in the range of 15-30 bar. In this case, the highest possible pressures are preferable from thermodynamic conditions.
  • the oxygen-containing gas required for the gasification and the water vapor which is generally required should be fed to the fluidized bed reactor of the gasification stage at different heights. It is expedient to supply water vapor predominantly in the form of fluidizing gas and oxygen-containing gas predominantly in the form of secondary gas. Of course, the entry of minor amounts of water vapor can also take place together with the oxygen-containing secondary gas and the entry of minor amounts of oxygen-containing gases together with water vapor as the fluidizing gas.
  • the residence time of the gases in the gasification stage - calculated above the entry point of the carbon-containing material - should be set to 3 to 20 seconds, preferably 10 to 15 seconds. This condition is usually realized by entering the carbonaceous material at a higher level in the gasification stage. On the one hand, this produces a gas that is richer in hydrocarbon and has a correspondingly higher calorific value, and on the other hand ensures that the gas has practically no hydrocarbons condensing in the exhaust system.
  • the desulfurization of the fuel gas is expediently carried out using a desulfurization agent tein whose particle size dp50 is 5 to 200 ⁇ m.
  • An average suspension density of 0.1 to 10 kgfm 3 , preferably 1 to 5 kg / m 3 , and an hourly solids circulation rate which is at least 5 times the solids weight in the reactor shaft should be set in the fluidized bed reactor.
  • the dosage of the desulfurizing agent should be at least 1.2 to 2.0 times the stoichiometric requirement be. It should be noted that when using dolomite or burned dolomite, practically only the calcium component reacts with the sulfur compounds. In the case of in-situ desulfurization in the gasification reactor, the effective desulfurization agents introduced with the inorganic constituents of the carbon-containing material must also be taken into account.
  • the gas speed during desulfurization is set to approx. 1 to 5 m / sec depending on the gas pressure (calculated as empty pipe speed).
  • the entire desulfurization agent which is also required for the combustion stage, can be added to the gas desulfurization stage. In this way, the thermal energy required for heating and possibly for deacidification is extracted from the gas and thus the gasification and combustion stages are maintained.
  • the combustible constituents that are not converted in the gasification stage are considered to be difficult fuels, particularly with regard to environmentally friendly combustion.
  • the by-products from gas cleaning are also considered to be very difficult to process. They are advantageously processed in a further circulating fluidized bed.
  • the by-products from gas cleaning are removed in an environmentally friendly manner.
  • the loaded desulphurization agents coming from the gas cleaning stage in particular insofar as they are in sulfidic form, such as calcium sulfide, are sulfated and thereby converted into landfill-compatible compounds, such as calcium sulfate.
  • the heat of oxidation released during the sulfation process is also obtained as steam.
  • the other by-products, such as dust from gas dedusting are also converted into environmentally compatible products.
  • the combustion takes place in two stages with different amounts of oxygen-containing gases. Their advantage lies in "soft" combustion, which prevents local overheating. The staged combustion also largely suppresses NO x formation.
  • the fuel is fed into the zone between the supply points for oxygen-containing fluidizing gas and secondary gas.
  • an average suspension density of 15 to 100 kg / m 3 is expediently created above the upper gas supply by adjusting the amounts of fluidization and secondary gas, and at least a substantial part of the heat of combustion is removed by means of cooling surfaces located in the reactor space above the upper gas supply.
  • the gas velocities prevailing in the fluidized bed reactor above the secondary gas supply are usually above 5 m / s at normal pressure and can be up to 15 m / s, and the ratio of the diameter to the height of the fluidized bed reactor should be chosen such that gas residence times of 0.5 to 8 , 0 s, preferably 1 to 4s, can be obtained.
  • any gas which does not impair the nature of the exhaust gas can be used as the fluidizing gas.
  • Inert gases such as recirculated flue gas (exhaust gas), nitrogen and water vapor are also suitable.
  • exhaust gas recirculated flue gas
  • nitrogen and water vapor are also suitable.
  • oxygen-containing gas it is particularly advantageous to use oxygen-containing gas as the fluidizing gas.
  • a plurality of supply openings for secondary gas are advantageous within each entry level.
  • Another expedient embodiment of the combustion process consists in creating an average suspension density of 10 to 40 kg / m 3 above the upper gas supply by adjusting the amounts of fluidization and secondary gas, removing hot solids from the circulating fluidized bed and, in the fluidized state, by direct and indirect heat exchange cool and return at least a partial flow of cooled solid into the circulating fluidized bed.
  • the constant temperature can be achieved practically without changing the operating conditions prevailing in the fluidized bed reactor, that is to say, for example, without changing the suspension density, among other things, solely by controlled recycling of the cooled solid.
  • the recirculation rate is more or less high.
  • the combustion temperatures can be of very low temperatures, which are close above the Ignition limit are arbitrarily set up to very high temperatures, which are limited, for example, by softening the combustion residues. They can be between 650 and 950 ° C.
  • the output in steam generation can be increased without interfering with the gasification stage if the combustion stage is additionally fed with carbon-containing material.
  • the possibility of adding solid carbon-containing material separately to the combustion stage, particularly in the start-up phase, allows steam turbine operation to be started, regardless of the gasification residue of the gasification stage.
  • air as an oxygen-containing gas
  • air enriched with oxygen or technically pure oxygen can also be used.
  • air enriched with oxygen or technically pure oxygen can also be used.
  • Within the combustion stage it is possible to work at normal pressure, but also under pressure, up to about 10 bar.
  • Preferred refinements of the invention consist in generating the fuel gas by gasifying at least 80% by weight of the carbon content of the solid carbon-containing material or in cooling the desulfurized fuel gases to a temperature in the range from 350 to 600 ° C. and freeing them from halides.
  • the increase in the degree of gasification to at least 80% by weight is generally associated with the advantage that an additionally increased degree of efficiency is achieved.
  • the halides are removed dry using calcium oxide or hydroxide, in principle under the same process conditions that are mentioned with regard to the separate desulfurization of the fuel gases.
  • the predominant part of the fuel gas produced in the above described manner and purified is burned in a combustion chamber of stoichiometry to produce NO x -deficient flue gases, so that a flue gas containing at least 5 vol .-% oxygen is produced. Since the temperature of the flue gas has to be based on the operating conditions of the gas turbine and is usually set to the maximum permissible value under full load operation, the amount of oxygen-containing gases required for combustion will be selected such that this permissible maximum temperature is established. However, the minimum oxygen content of 5% by volume must not be undercut. If necessary, care must be taken to ensure that the fuel gas has a high calorific value.
  • the operating temperature of the gas turbine is currently a maximum of 1200 ° C.
  • a further advantageous embodiment of the invention provides to burn the optionally remaining portion of the fuel gas nahstöchiometrisch -deficient to form NO x flue gases to be cooled and a second Gasturbinezu election.
  • the permissible gas turbine inlet temperature should not be exceeded, but if possible not below.
  • This embodiment of the invention has a particularly advantageous effect in that a high degree of efficiency can be achieved even in the case of part-load operation.
  • the degree of conversion of the primary energy, such as coal, into fuel gas and steam and thus ultimately the overall efficiency of the combined gas / steam turbine process is essentially determined by the permissible inlet temperature of the flue gas for the gas turbine.
  • the ratio of the outputs from the gas turbine to the steam turbine increases with increasing permissible inlet temperature of the flue gases in favor of the gas turbine. This means that as the permissible inlet temperature of the flue gas rises, the extent of gasification increases, and thus that of residue combustion should be reduced.
  • gas inlet temperatures of 1200 ° C efficiencies of 45% can be achieved.
  • the figure shows a flow diagram of the method according to the invention in a simplified form.
  • the fuel gas is generated in the circulating fluidized bed illustrated by (1), which is supplied with oxygen-containing fluidizing gas or with steam or coal via the lines (2 or 3 or 4). It is fed via line (5) to a first heat exchanger (6) and from there to the device (7) for desulfurization. After passing through a further heat exchanger (8), the removal of hydrogen halide, in particular hydrogen chloride, takes place in the device (9) and the dedusting in device (10). The sorbents obtained in the devices (7 and 9), loaded with pollutants of the fuel gas, and the dusts obtained in the device (10) are discharged via the lines (11, 12, 13).
  • the fuel gas then passes through line (14) into the combustion chamber (15), which is additionally supplied with oxygen-containing gas via line (16).
  • the flue gas intended for driving the gas turbine (17) is generated in the combustion chamber (15) by superstoichiometric combustion.
  • the dosage of the oxygen-containing gas is selected in such a way that the optimum temperature is created for the operation of the gas turbine (17).
  • Part of the exhaust gas from the gas turbine (17) is fed to the circulating fluidized bed (20) for the combustion of the gasification residue via line (18 and 19) as fluidizing gas or as secondary gas. If necessary, fresh oxygen-containing fluidizing gas can be introduced by means of the blower (21).
  • the gasification residue is entered via line (22) together with the loaded sorbents and the dusts separated from the fuel gases. At the same time, further desulfurizing agent and, if necessary, additional coal can be fed to the circulating fluidized bed (20) (line 23).
  • the steam generated in the steam registers (24) of the circulating fluidized bed (20) is fed via line (25) to the steam turbines (26, 27 and 28) operated under high pressure, medium pressure and low pressure.
  • the exhaust gas from the circulating fluidized bed (20) passes through a further heat exchanger (29) into a dedusting system (30) and then into the chimney (31).
  • Oxygen-containing flue gas emerging from the gas turbine (17) and not required in the circulating fluidized bed (20) can be fed to a heat exchanger system (33) via line (32) and cooled there in a conventional manner. It then also gets into the chimney (31).
  • a second gas turbine (34) the commissioning of which is advantageous particularly in the case of partial load operation. It is preceded by a combustion chamber (35) with a waste heat boiler (36), which can also be designed as a wall-cooled combustion chamber.
  • a flue gas obtained by near-stoichiometric combustion.
  • the flue gas is generated from fuel gas supplied via line (37) and oxygen-containing gas supplied via line (38).
  • the exhaust gas from the gas turbine (34) passes through line (39) into line (32) and, as described above, is utilized.
  • the gas is then fed to the combustion chamber (15) via line (14) and burned there with 3.6 times the stoichiometric requirement for air which is introduced via line (16).
  • the resulting flue gas of 1100 ° C is then expanded in the gas turbine (17).
  • the exhaust gas from the gas turbine has a temperature of 550 ° C, a pressure of 1.35 bar, an oxygen content of 13 vol.% And an NO x content of 200 mg / standard m 3 .
  • the terminal power of the generator assigned to the gas turbine (17) is 97 MW.
  • the gasification residue of 26.7 t / h and the discharges from the devices (7, 9 and 10) in a total amount of 5.0 t / h are mixed with a mixing temperature of 955 ° C via line (22) of the circulating fluidized bed (20 ) forwarded. There, the combustion is performed with 25% excess of oxygen at 850 ° C.
  • the distribution of the volumes of fluidizing gas to secondary gas takes place in the ratio of 30:70, wherein the fluidizing gas to% air (fan 21) and 2/3 via line (18 ) supplied gas turbine exhaust gas and has a temperature of 300 ° C.
  • the secondary gas for the fluidized bed reactor (20) consists exclusively of gas turbine exhaust gas of 550 ° C (line 19).
  • a total of 10% by volume of the gas turbine exhaust gas thus reaches the circulating fluidized bed (20).
  • Steam of 100 bar and 535 ° C. is generated in the circulating fluidized bed (20) and is fed to the steam turbine set (26, 27 and 28) via line (25).
  • the generator assigned to these steam turbines delivers a net output of 116 MW.
  • the gas turbine exhaust gas (90% by volume) not used in the combustion process is fed via line (32) to the heat exchanger system (33), cooled there to 100 ° C. with preheating of condensate and generation of steam, and finally fed to the chimney (31).
  • the overall efficiency achieved in the present example is 42%, with the power shares of steam and gas turbines behaving as about 1: 0.83.
  • 40% of the fuel gas generated in the gasification stage (1) is burned with an air excess of 5% in the pressurized combustion chamber (35) to a flue gas of 1100 ° C and expanded in the gas turbine (34).
  • the exhaust gas from the gas turbine (34) has a temperature of 550 ° C, a pressure of approx. 1 bar and an oxygen content of approx. 1% by volume. It is cooled in the heat exchanger system (33) and placed in the chimney (31) at approx. 100 ° C.
  • the terminal power of the generator assigned to the gas turbine (34) is 26 MW.
  • the majority of the fuel gas, namely the remaining 60%, are fed via line (14) to the combustion chamber (15) and burned with the addition of 3.6 times stoichiometric air.
  • the resulting flue gas of 1100 ° C is then expanded in the gas turbine (17) and cooled to 550 ° C.
  • the gas turbine exhaust gas has an oxygen content of 13% by volume and a pressure of 1.35 bar.
  • the generator of the gas turbine (17) delivers a terminal power of 58 MW.
  • the gasification residue of 26.7 t / h and the discharges from the devices (7, 9 and 10) in a total amount of 5 t / h are fed through line (22) to the circulating fluidized bed (20) and at 850 ° C. there burnt an excess of oxygen of 25%.
  • the distribution of the volumes of fluidizing gas to secondary gas is 30:70, the fluidizing gas being composed of% of air (blower 21) and% of gas turbine exhaust gas supplied via line (18). Its temperature is 300 ° C.
  • the secondary gas for the fluidized bed reactor (20) consists exclusively of gas turbine exhaust gas of 550 ° C. (line 19). This means that a total of 17% by volume of the gas turbine exhaust gas reaches the circulating fluidized bed.
  • Steam of 100 bar and 535 ° C. is generated in the circulating fluidized bed (20) and is fed to the steam turbine set (26, 27 and 28) via line (25).
  • the generator of this steam turbine set delivers a net output of 129 MW.
  • Example 1 The exhaust gas from the circulating fluidized bed (20) and the gas turbine exhaust gas not used in the combustion process are carried out as in Example 1.
  • the overall efficiency is 42%.

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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)
  • Fluidized-Bed Combustion And Resonant Combustion (AREA)
  • Treating Waste Gases (AREA)
EP87200488A 1986-04-17 1987-03-17 Kombinierter Gas-/Dampfturbinen-Prozess Expired EP0249255B1 (de)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AT87200488T ATE40182T1 (de) 1986-04-17 1987-03-17 Kombinierter gas-/dampfturbinen-prozess.

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
DE19863612888 DE3612888A1 (de) 1986-04-17 1986-04-17 Kombinierter gas-/dampfturbinen-prozess
DE3612888 1986-04-17

Publications (2)

Publication Number Publication Date
EP0249255A1 EP0249255A1 (de) 1987-12-16
EP0249255B1 true EP0249255B1 (de) 1989-01-18

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EP87200488A Expired EP0249255B1 (de) 1986-04-17 1987-03-17 Kombinierter Gas-/Dampfturbinen-Prozess

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Country Link
US (1) US4996836A (el)
EP (1) EP0249255B1 (el)
JP (1) JPH0680294B2 (el)
CN (1) CN1011999B (el)
AT (1) ATE40182T1 (el)
AU (1) AU586923B2 (el)
CA (1) CA1297683C (el)
DE (2) DE3612888A1 (el)
ES (1) ES2007290B3 (el)
GR (2) GR880300114T1 (el)
IN (1) IN165413B (el)
PT (1) PT84712B (el)
ZA (1) ZA872750B (el)

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US4478039A (en) * 1980-12-29 1984-10-23 United Technologies Corporation Utilization of coal in a combined cycle powerplant
LU83085A1 (fr) * 1981-01-23 1982-09-10 Cockerill Procede de production d'energie au depart de charbon et installation a cet effet
DE3113993A1 (de) * 1981-04-07 1982-11-11 Metallgesellschaft Ag, 6000 Frankfurt Verfahren zur gleichzeitigen erzeugung von brenngas und prozesswaerme aus kohlenstoffhaltigen materialien
DE3338107A1 (de) * 1982-11-30 1984-05-30 BBC Aktiengesellschaft Brown, Boveri & Cie., Baden, Aargau Kohlegefeuertes kraftwerk mit wirbelschichtfeuerung
JPS59215906A (ja) * 1983-05-20 1984-12-05 Ishikawajima Harima Heavy Ind Co Ltd 石炭だき二段加熱複合サイクル発電装置
GB8327074D0 (en) * 1983-10-10 1983-11-09 English Electric Co Ltd Fluidised-bed heat and power plant

Also Published As

Publication number Publication date
AU586923B2 (en) 1989-07-27
PT84712A (de) 1987-05-01
JPS62251428A (ja) 1987-11-02
ZA872750B (en) 1988-12-28
CA1297683C (en) 1992-03-24
US4996836A (en) 1991-03-05
JPH0680294B2 (ja) 1994-10-12
IN165413B (el) 1989-10-14
EP0249255A1 (de) 1987-12-16
ATE40182T1 (de) 1989-02-15
CN87102746A (zh) 1987-11-04
GR3000048T3 (en) 1990-10-31
DE3612888A1 (de) 1987-10-29
ES2007290B3 (es) 1990-03-16
AU7174987A (en) 1987-10-22
PT84712B (pt) 1989-12-29
CN1011999B (zh) 1991-03-13
GR880300114T1 (en) 1989-03-08
DE3760042D1 (en) 1989-02-23

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