Turbo Exhaust CO₂ Separation

Abstract

Process for turbo exhaust gas CO 2 -Separation from exhaust gas cleaned of particles with liquid CO 2 -Extraction at condensation pressure, comprising the steps: A. In process step A, the exhaust gas (10a) is cooled and the water vapor (14a) contained in the exhaust gas is condensed and separated, except for a residual portion of water vapor corresponding to the saturation pressure of the water vapor in the gas mixture; B. The remaining gas mixture a (11a) is heated in process step B to the temperature required for the condensation of CO 2 compressed to the required pressure and cooled down; C. In process step C, the gas mixture a (11c) is heated in the multi-component heat exchanger (23) to the condensation temperature of CO 2 cooled and the remaining portion of water vapor condenses or freezes in the self-cleaning heat exchanger component (23a) and is deposited there; D. In process step D, the CO 2 (13) in CO2 -condenser (24a) and separated from the exhaust gas in liquid form, whereby the remaining gas mixture b (12a) still contains a residual amount of CO 2 according to the saturation pressure of CO 2 in the gas mixture; K. In process step K, the gas mixture b (12a) is adsorbed from the residual CO 2 cleaned; L. In process step L, the gas mixture b (12b) is expanded to such an extent that the cold of the expanded gas mixture b (12c) is sufficient for the CO to be removed. 2 -Ethalation enthalpy in CO 2 -capacitor (24a,) is sufficient; M. In process step M, the CO 2 -Proportion in the gas mixture a (11d) in CO 2 -Capacitor (24a,) condenses N. Subsequently, in process step N, the cold of the gas mixture b (12c) f in the heat exchanger component a (23f) is used for the cooling requirement in the multi-component heat exchanger (23); O. In process step O, the heated gas mixture c (12c) is expanded to atmospheric pressure in the gas turbine b (28b) while performing work; P. In process step P, the cold expanded gas mixture b (12e) is heated in the self-cleaning heat exchanger component (23a), and the heated gas mixture b (12f) absorbs the deposited H 2 O from process step C and is discharged into the atmosphere after exiting the self-cleaning heat exchanger component (23a).

Description

[0001] The invention relates to a method for separating carbon dioxide according to the preamble of claim 1 and to a device for separating carbon dioxide according to the preamble of claim 3.

[0002] The turbo exhaust CO 2 -Capture serves to relieve the atmosphere of climate-damaging CO 2 -Emissions from exhaust gases by reducing the CO 2 removed from the exhaust gases by condensation and the separated CO 2 either subsequently stored underground (CCS process - Carbon Capture and Storage) or for other purposes such as CO 2 -based plastics. The process of turbo exhaust CO 2 -Capture is one of the physical processes for capturing CO 2 from exhaust gases.

[0003] A 400MW combined cycle power plant (CCGT) emits approximately 1.2 million tonnes of CO 2per year (an equivalent coal-fired power plant emits 3.3 million tonnes of CO 2 per year). On average, a forest area of ​​1 ha can absorb approximately 4 t CO 2 per year. This single 400MW combined cycle power plant alone would require 300,000 hectares of forest to compensate for the CO2 emitted. 2 's need. Germany as a whole has a forest area of ​​1.2 million hectares, which only contributes to CO 2 Compensation from four of these power plants would be sufficient. Total annual energy consumption in Germany in 2017 was 2,591 TWh, of which 37.8% came from renewable energy production. The remaining 1,600 TWh would require 457 400 MW power plants to generate electricity. These would emit 550 (combined cycle) - 1,500 (coal) million tons of CO 2per year, and that's in Germany alone, which accounts for only 2.4% of global energy consumption. Electricity generation from renewable energy sources in Germany rose from 36% in 2017 to 37.8% in 2018. Energy production from fossil fuels is therefore unavoidable in the medium to long term. To truly mitigate or prevent a climate catastrophe, there is no alternative to capturing and underground storage of CO2. 2 from combustion gases. This separation must be carried out with a minimum of energy input. This is possible with the patent-pending Turbo Exhaust CO 2 -separation, which, depending on the type of exhaust gas, consumes 50-70% less energy than the CCS processes investigated so far.

[0004] The turbo exhaust gas CO 2 -Separation in all processes that generate exhaust gas, such as • in the separation of CO 2in the exhaust gases of biomass power plants, • the separation of CO 2 in the exhaust gases of combined cycle power plants, • the separation of CO 2 in the exhaust gases of coal-fired power plants, • the separation of CO 2 in the exhaust gases of boilers, • the separation of CO 2 in the exhaust gases of combustion engines, • the separation of CO 2 in the exhaust gases of gas turbines and • the separation of CO 2 in the exhaust gases of industrial burners.

[0005] A current overview of the state of research and development on CO capture and storage 2 from exhaust gases, the “Technology Report 2.3 CO 2 -Capture and Storage - CCS” of the Jülich Research Centre on 17 December 2017. For the CO 2According to this study, post-combustion processes are exclusively chemical absorption processes in research and development, as well as membrane-based processes at a very early stage of research (p. 9 of the report).

[0006] The main problems with chemical absorption are the decomposition of solvents in the presence of oxygen and other foreign substances (e.g. dust), high rates of solvent degradation by reactions with sulfur dioxide or nitrogen oxide, and the high energy consumption required for solvent regeneration (p. 17 of the report).

[0007] In contrast to the methods used so far for CO 2 -Capture and storage is considered uneconomical, since the physical processes for cryogenic CO 2-separation would require too much energy for the chillers and compressors used due to high condensation pressures and low condensation temperatures. However, this consideration took into account energy recovery options and the storage of the CO 2 neglected.

[0008] For safety reasons, only underground storage facilities with a minimum depth of 800 m are suitable. To be able to store CO2 at such a depth, the CO2 must be 2 Due to the pressure prevailing there and to maximize the utilization of the available storage volume, the gases must be in a supercritical state. This requires a minimum pressure of 74 bar at 31°C. However, since all CCS capture processes used to date capture CO 2 at normal pressure, it must be compressed to 74 bar before storage. For example, the CO produced in a 400MW combined cycle power plant would 2A minimum of a two-stage gas turbocompressor cascade is required, which would require an energy consumption of at least 16 MW. This means that in all CCS processes investigated so far, only the CO 2 almost as much energy is used for storage as for the complete “Turbo Exhaust CO 2 -deposition process”.

[0009] In addition, there are installation costs for the necessary turbo compressors, which amount to approximately 50% of the costs of a “turbo exhaust gas CO 2 -separation“ plant.

[0010] Further relevant prior art is WO 2012 / 174 418 A1.

[0011] Task of the invention of the turbo exhaust CO 2 -Capture is therefore a process for the complete, pure capture of CO 2from exhaust gases, which can be operated as a physical process without solvents and the associated problems and which also requires significantly less energy for the separation and processing for storage of the CO 2 than the CCS processes currently being tested.

[0012] This object is achieved by a process for separating carbon dioxide with the process steps of claim 1.

[0013] Further advantageous method steps which optimize the method according to claim 1 result from subclaim 2.

[0014] The object of the invention is also to provide a device for turbo exhaust gas CO 2 -Capture of liquid CO2 2 at condensation pressure from exhaust gas cleaned of particles, which is suitable for CO 2 completely pure from exhaust gases without solvents and with low energy consumption

[0015] This task is solved by a device for turbo exhaust gas CO 2 -Capture of liquid CO 2 at condensation pressure from exhaust gas cleaned of particles according to claim 3.

[0016] An advantageous further development of the device for turbo exhaust gas CO 2 -separation results from subclaim 4.

[0017] The following figures illustrate embodiments of the invention. The individual figures show: Fig. 1 Turbo exhaust gas CO process 2 -Capture with CO 2 -withdrawal in liquid form; Fig. 2 Turbo exhaust gas CO processes 2 -Capture with CO 2 -Extraction at supercritical pressure; Fig. 3 Schematic Turbo-Exhaust-CO 2 -Capture with CO 2 -withdrawal in liquid form; Fig. 4 Turbo exhaust CO diagram 2-Supercritical pressure separationExtraction for underground storage; Fig. 5 Turbo Exhaust CO Processes 2 -Separation with supercritical pressure - extraction for underground storage with 2-stage exhaust gas compression; Fig. 6 Energy flow diagram turbo exhaust gas CO 2 -Separation with high pressure CO 2 -Extraction and 2-stage exhaust gas compression;

[0018] The process of turbo exhaust gas CO 2 -Capture uses in the capture of CO 2 from exhaust gas that has been cleaned of particles, the following process steps: • Exhaust gas cooling to ambient temperature • Exhaust gas compression to the CO 2 -Condensing pressure with recooling to ambient temperature • Exhaust gas cooling to the CO 2 -Condensation temperature • Gas separation by CO 2 -Condensation and separation • Work-producing expansion of decomposed gases • Treatment of CO 2 for subsequent storage or use.

[0019] The turbo exhaust CO 2 Separation is characterized by the use of turbomachinery and heat exchangers for the compression and cooling of exhaust gases. Energy consumption is limited by the fact that the energy initially used for exhaust gas compression is partially recovered in subsequent process steps through the expansion of the separated gases in gas turbines. At the same time, the expansion of the separated gases generates the cooling required for the process. Although energy is lost between compression and expansion due to internal losses in the turbo compressors and gas turbines, these losses can be limited by the fact that isentropic efficiencies of better than 90% are state of the art in high-quality modern gas turbines and turbo compressors.

[0020] The central importance of turbomachinery in the capture of CO 2 and to distinguish it from the chemical CO 2 -separation process was named “Turbo-Exhaust-CO 2 -deposition” for the process. The turbo exhaust CO 2 -Capture has 2 process variants in which the CO 2 is taken from the process in a different physical state: • Process variant 1: Turbo exhaust gas CO 2 -Capture with CO 2 -Liquid withdrawal at condensation pressure, • Process variant 2: Turbo exhaust gas CO 2-Capture with CO 2 -Extraction at supercritical pressure for underground storage.

[0021] The greatest application potential lies in process variant 2, since with this process variant the CO 2 from power plant processes is processed in the most energy-efficient way to reduce the resulting huge CO 2 -to store large quantities underground and to remove climate-damaging CO 2 -To completely avoid power plant emissions into the atmosphere in the future.

[0022] Power plants operated with fossil fuels would thus become climate neutral, while biomass power plants would become climate positive, as the biomass releases CO into the atmosphere during its growth. 2 withdraws. The process of global warming by atmospheric CO 2 is reversed! Description Variant 1 (Figures 1 and 3)

[0023] The turbo exhaust CO 2 -Capture with removal of CO 2in liquid form is divided into the following process steps: 1. Preliminary stage exhaust gas purification The exhaust gas 10 to be treated must be before the turbo exhaust CO 2 -Separation of particles such as dust, fly ash, and soot particles. The particle load of the exhaust gas 10 is highly dependent on the upstream combustion process. Depending on the type and intensity of the particulate load, 20 different filter and separation technologies are used in the exhaust gas purification stage, such as electrostatic precipitators, centrifugal separators, fabric filters, or scrubbers. Depending on the requirements of turbomachinery manufacturers, very thorough removal of particles from the exhaust gas may be necessary. There are suitable techniques for cleaning the exhaust gases from all combustion processes as an upstream stage for turbo exhaust CO 2-separation. However, this is not part of the process, so a detailed description of exhaust gas purification is not necessary here. 2. Process step A In process step A, the exhaust gas 10a, purified of particles, is cooled in the exhaust gas cooler 21a. A large portion of the water vapor contained in the exhaust gas condenses and is separated as condensate 14a. The temperature at which the exhaust gas enters the turbo exhaust CO 2 The temperature at which the deposition occurs has a wide temperature spectrum depending on the upstream combustion process (e.g. 50 °C in a motor CHP unit and several hundred °C behind a single-stage gas turbine), so that the amount of heat that has to be removed in process step a varies greatly. Cooling in the exhaust gas cooler a 21a is achieved with cooling water and is limited by the temperature of the available cooling water 16, which must usually be obtained using a cooling tower 21. At some locations, cooling water from the sea or rivers may also be available. Depending on the location and season, this exhaust gas cooling system can cool the exhaust gas to a temperature range between +5 °C and +30 °C. 3. Process step B In process step B, the cooled and dried exhaust gas 11a, consisting of N 2 , CO 2 , Ar and residues of H 2O is compressed in the exhaust gas turbocompressor 22 to a pressure above 5.16 bar and then recooled in the exhaust gas cooler b 21b. When cooling water 16 is used, the temperature range between +5 °C and +30 °C described above can be achieved again during recooling. The majority of the water vapor contained in the exhaust gas condenses and is separated as condensate 14b. In the exhaust gas turbocompressor 22, the compression level must be selected so high that the required cooling for the process can be generated during expansion and heating of the gas mixture b 12. The calculations performed for several exemplary embodiments showed that a compression of 6 to 15 bar is sufficient for this purpose. At higher compression, the CO 2can be liquefied at higher temperatures, but the higher energy consumption required for the additional compression of the exhaust gas reduces the economic efficiency. For exhaust gas compression, over 90% of the turbo exhaust CO 2 The energy required for exhaust gas separation is consumed. Lower energy consumption for exhaust gas compression can be achieved through multi-stage compression with intercooling. The energy required for exhaust gas compression decreases with the number of compression stages. In return, higher investment costs are required for the additional compression stages. In single-stage compression in the Fig. 3 and Fig. 4, the drive energy 30 must be used for the compressor 22. In a two-stage compression in Fig.5, drive energy 30a is required for the first compressor stage 22a, and drive energy 30b for the second compressor stage 22b. The same applies if the compression is divided into even more compression stages. The sum of the drive energy 30a, 30b for the two-stage compression is smaller than the drive energy (30) for the single-stage compression. When designing the Turbo-CO 2 -Separation for specific applications, a project-specific optimum can be determined by means of an economic calculation from the reduced energy costs for several compressor stages and the resulting increase in investment costs. 4. Process step C The compressed and recooled gas mixture a 11c is heated in process step C in the multi-component heat exchanger 23 to the condensation temperature of the CO 2 cooled down. The exhaust gas 11c, when leaving the exhaust gas cooler(s) 21b, still has a considerable water content as saturated, moist exhaust gas, which at 25°C and 7 bar amounts to approximately 2.8 g per kg of gas. Therefore, when cooling the exhaust gas 11c below the freezing point of water, a self-cleaning heat exchanger component 23a is required to cool the exhaust gas. This is because, during this cooling, the water vapor still contained in the gas mixture 11c condenses or freezes, deposits on the walls of the heat exchanger component 23a, and without cleaning measures, the heat exchanger component 23a would become clogged. In the self-cleaning heat exchanger component 23a, the ice deposited on the walls of the heat exchanger and the condensed water are absorbed by the gas mixture b 12f discharged into the atmosphere by periodically switching the flow with the motor flaps 23b, 23c and the check valves 23d, 23e, thus completely cleaning the heat exchanger. Self-cleaning heat exchangers are well-known components in air separation plants. Basically, for the turbo exhaust CO 2 For separation, all types of self-cleaning heat exchangers known from air separation plants are suitable. For example, cross-flow counterflow heat exchangers, stone-filled regenerators with built-in coils, or compact recuperators (often referred to as reversing exchangers). The self-cleaning multi-component heat exchangers integrate the heat exchanger components of the heat-emitting side and the heat-absorbing side and other heat exchanger components, such as a heat exchanger 23f - e.g. as a built-in coil - for the heat absorption of the gas mixture b 12c after the CO 2 -Capacitor 24a. In the self-cleaning multi-component heat exchanger 23, the following heat quantities must be removed from the gas mixture a 11c: • the enthalpy difference of the gas mixture a 11c from the outlet temperature of the last exhaust gas cooler 21c to the condensation temperature of the CO 2 and • the evaporation enthalpy of the condensing water vapor. The cooling required for the heat-absorbing side of the multi-component heat exchanger 23 is provided • by heating the cold gas mixture b 12c in the heat exchanger component 23f and • by heating the cold gas mixture b 12e, which has been expanded to atmospheric pressure in the gas turbine b 28b, in the self-cleaning heat exchanger component 23a. 5. Process step D In process step D, the condensation and separation of the CO 2 from the exhaust gas stream 11d cooled and compressed to separation temperature and pressure. The condensation of the CO 2 in CO 2 -Capacitor (24a). The CO 2-Condenser 24a is a specially developed apparatus that meets the requirements for operation with condensation temperatures just above the solid / liquid phase boundary and, in the interest of energy efficiency, operates exclusively with cold from the expansion of the gas mixture b 12c. The condensation temperature of CO 2 lies relatively close to the triple point of CO 2 , At 7 bar condensation pressure, the condensation temperature of the CO 2 at 224 °K, only 7.5 °K above the 216.5 °K at the triple point. The temperature of the exhaust gas 11d must not exceed 11 °C at any point in the CO 2 -Capacitor 24a below the sublimation temperature of CO 2 drop, as otherwise heat exchangers and pipes would become clogged. Therefore, high demands are placed on the temperature control of the CO 2 -Capacitor 24a. After the CO 2 -Condensation occurs in CO 2 -Separator 24c separates the liquid CO 213 and the remaining gas mixture b 12a. 6. Process step K The CO 2 -Separator 24a coming gas mixture b 12a with the components N 2 and Ar 13a contains a CO 2 -Proportion corresponding to the saturation pressure of CO 2 at the temperature in the gas mixture b 12a, which would condense or freeze out upon further cooling of the gas mixture b 12a. Therefore, this CO 2 -portion from the gas mixture b 12a with the help of CO 2 -adsorbers 25a, 25b. Conventional CO 2 Adsorbers operate as molecular sieve adsorbers with zeolites as adsorption material in alternating operation. Two adsorbers are used. While one adsorber is in operation alternately and CO 2The second adsorber is regenerated using a purge gas. The purge gas must be dry, free of carbon dioxide and hydrocarbons, and heated to approximately 100 °C. In the case of the Turbo Exhaust CO 2 For separation, the gas mixture b 12e is suitable as a purge gas. Waste heat can be used for gas heating, e.g., the heat of the exhaust gas 11b after exiting the exhaust gas compressor 22. 7. Process step L In process step L, the purified gas mixture b 12b is expanded in the gas turbine a 28a to such an extent that the cold of the expanded gas mixture b 12c is sufficient for the CO 2 -condensation enthalpy of vaporization (process step M) is sufficient. 8. Process step M In process step M, the expansion cooling of the gas mixture b is used to condense the CO 2 -proportion in the gas mixture a in CO 2 -Capacitor 24a used. 9. Process step N Subsequently, in process step N, the cold of the gas mixture b 12c is used for heat transfer in the heat exchanger component 23f, which is integrated into the multi-component heat exchanger 23, for the cooling requirement in the multi-component heat exchanger 23. 10. Process step O In process step O, the heated gas mixture b 12c is expanded to atmospheric pressure in the gas turbine b 28b, performing work. 11. Process step P In process step P, the cold expanded gas mixture b 12e is heated in the multi-component heat exchanger 23 and the heated gas mixture b 12e is used for backflushing the self-cleaning heat exchanger component 23a. During heating during passage through the self-cleaning heat exchanger component 23a, the gas mixture b absorbs the condensed or frozen H 2O. The moist gas mixture b 12e is then produced without any climate-damaging CO 2 released into the atmosphere. Description Variant 2 (Figures 2 and 4)

[0024] With the turbo exhaust CO 2 -Capture with CO 2 -Extraction at supercritical pressure, exhaust gas cleaned of particles is treated as follows. 1. Process steps A and B

[0025] The treatment of the exhaust gas in process steps A and B is identical to the treatment in process variant 1, the turbo exhaust gas CO 2 -Separation with liquid extraction of CO 2 at condensation pressure. 2. Process step C

[0026] Process step C is also largely the same as process variant 1, but in order to provide the required cold, the supercritically compressed CO 213a in the heat exchanger component 23g, which is additionally integrated into the multi-component heat exchanger 23. 3. Process step D

[0027] In process step D, the CO 2 condensed and separated, as with liquid CO 2 -Withdrawal at condensation pressure, but for further treatment in a CO 2 -High pressure pump 24e forwarded. 4. Process step F

[0028] In process step F, the liquid CO 2 13 with the CO 2The high-pressure pump 24e compresses the material to the supercritical pressure required for underground storage and then feeds it into the heat exchanger component 23g. From an energy perspective, compressing a substance in the liquid state is particularly advantageous, since the energy required to compress liquids in the liquid state is many times lower than that required to compress gases. The degree of compression required depends on the pressure required for storage in the respective storage facility.

[0029] As the compression pressure increases, so do the demands on the transport equipment - with the very large CO 2 -Quantities from power plants is a CO 2 Pipeline transport is an appropriate technology. The compression pressure chosen for the CO 2of 100 bar can be considered cost-effectively feasible according to the state of the art, since this pressure is also used in high-pressure transmission pipelines for natural gas. 5. Process step G

[0030] In process step G, the supercritical CO 2 13a is heated to ambient temperature in the heat exchanger component b 23g. After heating in the heat exchanger component b 23g, the highly compressed CO 2 13b from the turbo exhaust CO 2 -separation and transported, for example, to an underground storage facility. At the compression pressure chosen for the CO 2 of 100 bar at 290 °K the specific volume is 1.138 dm 3 / kg or the density 0.879 kg / dm 3 . The compression of the CO 2 is therefore sufficient for underground storage depths of more than 800 m (minimum storage depth for CO 2-final repository) and the pressure prevailing at this depth and to make maximum use of the available storage volume. 6. Process steps K, L, M, N, O and P

[0031] The CO 2 Condensation and CO 2 -separation in process step D separated gas mixture b 12a is used in the turbo exhaust gas CO 2 -Capture with CO 2 -Extraction at supercritical pressure in process steps K, L, M, N, O and P is treated identically as in process variant 1. Advantages of CO 2 -Extraction at supercritical pressure

[0032] The compression and heating of the liquid CO separated at condensation pressure and low temperature 2 in variant 1, to supercritical storage pressure and heating to ambient temperature in variant 2 is the crucial step to reduce the CO 2to be able to store it underground and keep the exhaust gas out of the atmosphere.

[0033] Due to the heat absorption of the supercritical CO 2 13b in the heat exchanger component 23g, an additional compressor work of 30 can be saved compared to variant 1. Apparatus for turbo exhaust CO2 separation

[0034] The essential parts and components of the apparatus for the turbo exhaust gas CO 2 -separation are turbo compressors, expansion turbines, heat exchangers and CO 2 -adsorber. Apparatus 1 for the turbo exhaust gas CO 2 Capture with CO 2 -Liquid withdrawal at condensation pressure

[0035] In the apparatus for turbo exhaust gas CO 2 -Capture with CO 2-Withdrawal in liquid state at condensation pressure, the cleaned exhaust gas 10a coming from the upstream combustion process is passed through the exhaust pipe a 40a into the exhaust gas cooler a 21a. After the exhaust gas has been cooled and dried there, the cooled gas mixture a 11a is passed on to the downstream exhaust gas compressor 22 through the exhaust pipe b 40b. To cool the exhaust gas, the exhaust gas cooler is connected to the pipes of the cooling water circuit 21g, on the supply side to the cooling water line a 43a and on the return side to the cooling water line b 43b. Before it leaves the exhaust gas cooler 21a, a separator integrated into the exhaust gas cooler prevents the water condensed in the exhaust gas cooler from being carried further by the exhaust gas flow. In the exhaust gas cooler a 21a, the condensate a 14a is collected at the bottom and discharged via the drainage line a 44a connected to the exhaust gas cooler.

[0036] The exhaust gas supplied to the exhaust gas compressor 22 via the exhaust gas duct b 40b is compressed there to the condensation pressure of the CO 2 compressed. The exhaust gas is passed from the exhaust gas compressor 22 to the gas cooler b 21b via the gas pipe c 40c. To cool the exhaust gas, the exhaust gas cooler b 21b is connected to the pipes of the cooling water circuit 21g, on the supply side to the cooling water line c 43c and on the return side to the cooling water line d 43d. Before exiting the exhaust gas cooler 21b, a separator integrated into the exhaust gas cooler prevents the water condensed in the exhaust gas cooler from being carried further by the exhaust gas flow. In the exhaust gas cooler b 21b, the condensate b 14b is collected at the bottom and discharged via the drainage line b 44b connected to the exhaust gas cooler.

[0037] From the outlet of the exhaust gas cooler 21b, the gas mixture a 11c is transported through the gas pipe d 40d into the self-cleaning heat exchanger component 23a.

[0038] The gas pipe d 40d is divided into two parallel lines by a T-piece upstream of the self-cleaning heat exchanger component 23a, one of which is used in shuttle operation by the exhaust gas for the outward journey and the other line by the exhaust gas after the CO 2-separation of the remaining gas mixture b 12e is used as a path in the opposite direction. To switch between the gas paths, two motorized flaps 23b operated by the control system are installed behind the T-piece in the parallel lines of the gas mixture a on the heat-emitting side of the self-regulating heat exchanger component 23a. Two motorized flaps 23c operated by the control system are also installed in the parallel lines of the gas mixture b flowing in the opposite direction on the heat-absorbing side, before the parallel lines are rejoined by installing a T-piece. On the cold side of the self-cleaning heat exchanger component 23a, two check valves 23d are installed in the parallel lines of the gas mixture a 11d before the parallel lines for the gas mixture a are rejoined via a T-piece.The nitrogen pipe f 42f for the gas mixture b 12e flowing in the opposite direction is divided into the two parallel gas lines by a T-piece on the cold side of the self-cleaning heat exchanger component and here, too, two non-return valves 23e are installed in the parallel gas lines for the gas mixture b.

[0039] In the self-cleaning heat exchanger component 23a, heat exchanger surfaces are arranged between the two opposing gas mixtures a 11c and b 12e, which flow in opposite directions. These surfaces facilitate heat transfer between the gases and prevent material mixing. In the version with two stone-filled regenerators, which is also possible for the self-cleaning heat exchanger component 23a, the regenerators are operated in oscillating mode in the direction of the gas mixture a 11c to be separated, or in the opposite direction when flowing through the gas mixture b 12e, with periodic switching.

[0040] To meet the cooling demand, the heat exchanger component a 23f for the cooling utilization of the gas mixture b 12c is installed in the multi-component heat exchanger 23. On the cold side, the heat exchanger component a 23f is connected to the nitrogen pipe d 42d and on the hot side to the nitrogen pipe e 42e.

[0041] The gas mixture a 11d, which is reunited in the T-piece, is fed through the gas pipe g 40g to the CO 2 -condenser 24a and connected there to the heat-emitting side 24b. At the outlet of the CO 2 -Capacitor 24a is the CO 2 -portion in the gas mixture a 11e is condensed and the gas mixture a 11e is fed via the gas pipe h 40h into the CO 2 separator 24d. From the CO 2 -Separator 24d the condensed CO 2 taken via a sump-side connection and via the CO 2 -Pipe a 41a is supplied for subsequent use.

[0042] The gas mixture b 12a, which after separation of the CO 2 remains, is taken from the CO 2 separator and through the nitrogen pipe a 42a into the CO 2 -Adsorbers 25a, 25b, which, as molecular sieve adsorbers with zeolites as adsorption material in oscillating operation, remove the remaining CO present in the gas mixture b 12a 2 The gas mixture b 12a flows through the two control-operated switching valves 25c or 25e, which are installed upstream of the adsorbers and which, together with the two control-operated switching valves 25d or 25f, which are installed downstream of the adsorbers, ensure the alternating use of the two adsorbers.

[0043] From CO 2 -Adsorber 25a, 25b, the gas mixture b 12b is passed through the nitrogen pipe b 42b to the gas turbine a 28a and expanded there to perform work.

[0044] From the outlet of the gas turbine a 28a, the gas mixture b 12c is led through the nitrogen pipe c 42c to the heat-absorbing side 27b of the coolant / gas heat exchanger 27a. In the coolant / gas heat exchanger 27a, the cold of the expanded gas mixture b 12c is transferred to the coolant 15. On the heat-absorbing side 27c, the coolant / gas heat exchanger 27a is connected to the pipes 45a and 45b of the refrigeration circuit 27. Via the refrigeration pipes a 45a, the cold from the coolant / gas heat exchanger 27a is transferred to the CO 2 -condenser 24a and through the control valve b 27d and the control of the coolant pump 27e, the coolant 15 is adjusted in temperature and flow rate exactly to the cooling requirement in the CO 2 -Condenser 24a conditioned. The return flow of the coolant 15 from the CO 2 -Condenser 24a to the coolant / gas heat exchanger 27a is via the cooling pipe b 45b.

[0045] The gas mixture b 12c is led from the outlet of the coolant / gas heat exchanger 27a through the nitrogen pipe d 42d to the connection to the heat exchanger component a 23f, which is installed in the multi-component heat exchanger 23. After heating in the heat exchanger component 23f, the gas mixture b 12c is led from the outlet of the heat exchanger 23 through the nitrogen pipe e 42e to the inlet of the gas turbine b 28b, where it expands to perform work.

[0046] The expanded gas mixture b 12e is conducted from the outlet of the gas turbine b 28b through the nitrogen pipe f 42f to the T-piece on the cold side of the self-cleaning heat exchanger component 23a and then, as described above, alternately along the alternating gas paths through the self-cleaning heat exchanger component 23a. In the self-cleaning heat exchanger component 23a, the heat exchange described above takes place with the gas mixture a 11c to the gas mixture b 12e, and the heated gas mixture b 12f absorbs the water deposited on the wall surfaces of the self-cleaning heat exchanger component 23a. After exiting the T-piece on the warm side of the self-cleaning heat exchanger 23, the gas mixture b 12f is discharged to the atmosphere via the nitrogen pipe g 42g. Apparatus 2 for the turbo exhaust CO 2 Capture with CO 2 -Extraction at supercritical pressure

[0047] The structure of apparatus 2 is identical up to the sump-side outlet of the CO 2 from the CO 2 -Separator 24d via the CO 2 -Tube a 41a with the structure of apparatus 1, with the addition that in addition to the multi-component heat exchanger 23, the heat exchanger component b 23g for heating the supercritically compressed CO 2 is installed.

[0048] In apparatus 2, the condensed CO 2 13 from CO 2 -separator 24d via a sump-side connection and via the CO 2 -Pipe a 41a into the CO 2 -High pressure pump 24e and compressed there to the supercritical pressure required for underground storage.

[0049] The CO 2 -High pressure pump 24e compressed CO to supercritical pressure 2 13a is about the CO 2-Pipe b 41b into the heat exchanger component b 23g, flows through the heat exchanger component b 23g and absorbs heat. The CO heated in the heat exchanger 23g 2 13b is caused by the CO 2 -Pipe c 41c to connection point b for the CO 2 - Further transport 24g.

[0050] The structure of the apparatus 2 for the treatment of the gas mixture b 12a, which after separation of the CO 2 via a head-side connection from the CO 2 -separator 24d corresponds completely to the structure in apparatus 1. Apparatus 1 to 2 for the turbo exhaust gas CO 2 -Separation of sulfur-containing fuels

[0051] When sulphur-containing fuels are burned, the exhaust gas contains SO 2 and SO 3 which react further to form sulphurous acid and sulphuric acid when the water vapor in the exhaust gas condenses.

[0052] The acid dew point of sulfur-containing fuels is in the range of 120° to 150 °C. This temperature is not reached in the exhaust gas heat exchanger a 21a and in the exhaust gas heat exchanger b 21b, 21c.

[0053] Falling below this value means that highly corrosive sulfuric acid condenses and attacks the wall. Therefore, when using sulfur-containing fuels, the exhaust gas heat exchangers a 21a-21c must be made of corrosion-resistant materials such as plastics or low-corrosion, high-alloy steels (for example, those with the material number 1.4571 (V4A)).

[0054] When treating sulfur-containing exhaust gases, the condensate from the exhaust gas heat exchangers a 14a-14c is acidic, which must also be taken into account during subsequent disposal or use.

[0055] SO 2 and SO 3-Gas components that have not reacted with the condensing water vapor 14a condense when the gaseous / liquid phase boundary is exceeded at the higher pressure of the gas mixture a 11b) in the gas heat exchangers 21b, 21c and are separated there in liquid form 14b and 14c. Economic efficiency and energy consumption of turbo exhaust CO2 capture

[0056] The turbo exhaust CO 2 As explained above, capture can be applied to a wide variety of combustion processes, so general statements regarding costs, economic efficiency, and energy consumption are not possible. Rather, the economic and energy impacts must be individually examined and calculated for each application.

[0057] The turbo exhaust CO 2 -Capture, like any other CO 2 -Capture the use of energy for the separation of CO 2Depending on the use, further energy expenditure is required for the storage or further processing of the CO 2 , which, as already mentioned at the beginning, is used in the turbo exhaust gas CO 2 -Capture is negligible compared to other CCS capture processes.

[0058] In this patent application, the use of turbo exhaust gas CO 2 -separation for the treatment of exhaust gases from a modern, highly efficient combined cycle power plant.

[0059] The calculation example for the combined cycle power plant assumes approximately 400 MW of electrical power and an electrical efficiency without CO 2 -separation of 60% and is attached as an appendix. When the CO 2 At supercritical pressure of 100 bar, the electrical efficiency of the combined cycle power plant in the calculation example drops from 60% to around 56%.

[0060] In case the CO 2at an evaporation pressure of approximately 6 bar, the electrical efficiency of the combined cycle power plant drops slightly less, from 60% to approximately 57%.

[0061] General statements on the economic impact of the turbo exhaust gas CO 2 -Capture of saved CO 2 Emissions are difficult to control because the current certificate trading system has market-dependent prices. The current CO2 tax law provides for a CO 2 -Tax of 25 € / t CO 2 with an increase to 55 € / t CO 2 in 2025.

[0062] The following is an example calculation assuming that the power plant's revenues from electricity sales are €45 / MWh (average price 2018). The savings achieved through the use of turbo exhaust gas CO 2 The sales revenues for electricity lost due to the capture of CO2 can be calculated as follows: Electricity revenue per hour 45 € / MWh Output 400 MW combined cycle power plant without turbo exhaust CO 2 -separation 403 MW Output 400 MW combined cycle power plant with turbo exhaust CO 2 -separation 372 MW Electricity sales per hour without turbo exhaust CO 2 -separation 18.135 € Electricity sales per hour with turbo exhaust CO 2 -separation 16.740 € Loss of sales revenue per hour 1.395 €

[0063] With a tax rate of €25.00 / t from 2021, the tax on the turbo exhaust gas CO 2 Calculate the tax savings achieved through deposition as follows: Savings of 400 MW combined cycle power plant CO 2 Emissions per Hour 136 t / h CO 2 -Tax from 2021 25,00 € / t Saving CO 2 -Tax per hour 3.400,00 €

[0064] The comparison of reduced sales revenue with saved CO 2 -tax results in a saving for the 400MW combined cycle power plant of €14.6 million per year if the power plant is equipped with the turbo exhaust gas CO 2 -separation is carried out. Even taking into account the high investment and operating costs of the turbo exhaust CO 2 -separation plant and the additional costs incurred by underground storage, the comparison shows the enormous economic potential of the turbo exhaust CO 2 -separation.

[0065] Beyond the economic considerations, the enormous ecological advantage for reducing CO 2 Concentration in the atmosphere due to • the avoidance of further climate-damaging CO2 -emissions, or • reversing climate damage caused by biomass power plants through turbo exhaust CO 2 -separation and underground storage must be taken into account. Calculation example 0. Explanation of the calculation example for turbo exhaust CO 2 -separation

[0066] The calculation example is a combined cycle power plant with approximately 400 kW electrical output, an electrical efficiency of 60% and operation with natural gas H as fuel. For clarity, the calculation assumes that the compressors and turbines of the turbo exhaust gas CO 2 Separation must be arranged on the same shaft as the combined cycle turbines. If this is not the case, the following results must be corrected for the electrical efficiencies of the motors and generators.

[0067] The calculation is made for the application case that the CO 2is removed from the process at supercritical pressure for underground storage, 1. Compilations 1.1 Energy balance and efficiency loss of the combined cycle power plant with turbo exhaust gas CO2 capture and CO2 removal at 100 bar Fuel use 671,400 kW 100,0000% Electrical power plant without turbo- Exhaust CO 2 -separation 402,840 kW 60,0000% Exhaust gas compressor 1st stage -22,259 kW -3,3153% Calculation c Exhaust gas compressor 2nd stage -21,224 kW -3,1612% Calculation of CO 2 -High-pressure pump -359 kW -0,0535% Calculation e Auxiliary equipment (pumps, cooling tower, etc. estimated) -100 kW -0,0149% Gas turbine a 13,645 kW 2,0324% Calculation f Gas turbine b 3,589 kW 0,5346% Calculation g Electrical power plant with turbo exhaust CO2 capture 372,543 kW 56,0221 % 1.2 Balance of the CO2 condenser Cooling requirements Cooling capacity Condensation CO 2 12,657 kW Calculation h Reserve + losses CO 2 -Refrigerant condenser 446 kW 1. Heating of the gas mixture b (stage 1) -13,103 kW Calculation k 13,103 kW -13,103 kW 1.3 Balance of the multi-component heat exchanger Cooling requirements Cooling capacity Cooling gas mixture a 15,666 kW Calculation j Reserve + losses of self-cleaning WT 3,568 kW Condensation H 2 O in the self-cleaning WT 1,507 kW Calculation j 1. Heating of the gas mixture b (stage 2) -2,891 kW Calculation k 2.Heating of the gas mixture b -12,649 kW Calculation I Warming CO2 -5,201 kW Calculation m 20,741 kW -20,741 kW 2. Calculations 2.1. Calculation a - Determination of exhaust gas mass flow and exhaust gas composition Composition of dry, clean air O 2 0,209 m 3 / m 3 N 2 0,781 m 3 / m 3 Ar 0,009 m 3 / m 3 other 0,000 m 3 / m 3 1,000 m 3 / m 3 Fuel natural gas H Molecular volume Nm 3 / Kmol Molecular weight kg / N m 3 Shares Quantity CH 4 22,38 16,00 93% Quantity C 2 H 6 22,24 28,00 3% Quantity C 2 H 6 22,24 28,00 2% Quantity H 2 22,43 2,00 Amount of CO 22,40 28,00 Menge CO 2 22,26 44,00 1% Quantity O 2 22,39 32,00 Quantity S 22,41 32,00 Quantity N 2 22,40 28,00 1% Quantity H 2 O 22,40 18,00 argon 22,39 40,00 in total 100% Fuel quantity 18 Nm 3 / s 64.800 Nm 3 / h Menge O 2min = 2*CH 4 +3.5*C 2 H 6 +5*C 3 H 8 2.050 m 3 / m 3 37 Nm 3 / s 53 kg / s Calorific value H u in kJ / Nm 3 37.300 Calorific value H u in kWh / Nm 3 10,36 671,400 kW electrical efficiency 60% electrical power 402,840 kW Calculation of the exhaust gas mass flow Menge CO 2 1.050 m 3 / m 19 Nm 3 / s 37.71 kg / s Quantity H 2 O from combustion 2.030 m 3 / m 3 37 Nm 3 / s 52.22 kg / s Amount of SO 2 from combustion 0.00 kg / s Quantity N 2 138 Nm 3 / s 172.11 kg / s Quantity Ar 2 Nm 3 / s 2.94 kg / s Total exhaust gas 264.99 kg / s of which dry exhaust gas 212.77 kg / s 2.2. Calculation b - Determination of the isentropic exponents for the gas mixtures Determination of the isentropic exponent for the gas mixture a (N 2 / CO 2 / Ar) mN2 172.11 kg / s m CO2 37.71 kg / s m Ar 2.94 kg / s m Ges = m N2 + m CO2 + m Ar 212.77 kg / s specific heat capacity N 2 C p N2 1.041 kJ / kgK specific heat capacity N 2 C v N2 0.744 kJ / kgK specific heat capacity CO 2 c p CO2 0.822 kJ / kgK C v CO2 0.637 kJ / kgK specific heat capacity Ar C p Ar 0.519 kJ / kgK C v Ar 0.309 kJ / kgK Isentropic exponent of N 2 K 1,4 Isentropic exponent of CO 2 K 1,29 Isentropic exponent of Ar K 1,67 c p, Ges = m N2 / m Ges * c p N2 + m CO2 / m Ges * cp CO2 + m AR / m Ges * cp Ar 0,994975 c v, Ges = m N2 / m Ges * c v N2 + m CO2 / m Ges * c vCO2 + m AR / m Ges * c p Ar 0,718719 KGes 1,384372 Determination of the isentropic exponent for the gas mixture b m N2 / Ar = m N2 + m ar 175 kg / s c p, Ges = m N2 / m Ges * c p N2 + m AR / m Ges * cp Ar 1,032242 c v, Ges = m N2 / m Ges * c v N2 + m AR / m Ges * c p Ar 0,736280 KN2 / Ar 1,401969 2.3 Calculation c Performance of the exhaust gas compressor - 1st stage Gas inlet temperature t l 25 °C Environmental pressure p 1 1.00 bar Pressure after turbo compressor P2 2.70 bar isentropic turbocompressor efficiency or i,TVD 90,00% Isentropic exponent gas mixture a K 1,384372 Enthalpy exhaust gas at the inlet of the turbo compressor h 1 = c p Ges * t 1 24.87 kJ / kg Enthalpy exhaust gas at the outlet of the turbo compressor h TVD = h 1 +1 / η i,VD * c p Ges * (t TVD + 273) * [(p2 / p1) (k-1) / k -1] 129.5 kJ / kg Outlet temperature from the turbo compressor t 2 t TVD = h TVD / c p 130 °C Performance of exhaust gas compressor 1 22,259 kW 2.4 Calculation of the performance of the exhaust gas compressor - 2nd stage Gas inlet temperature t l 25 °C Environmental pressure p 1 2.70 bar Pressure after turbo compressor P2 7.00 bar isentropic turbocompressor efficiency or i,TVD 90,00% Isentropic exponent gas mixture a K 1,384372 Enthalpy exhaust gas at the inlet of the turbo compressor h 1 = c p Ges * t 1 24.87 kJ / kg Enthalpy exhaust gas at the outlet of the turbo compressor h TVD = h 1 +1 / η i,VD * c p Ges * (t TVD + 273) * [(p2 / p1) (k-1) / k -1] 124.6 kJ / kg Outlet temperature from the turbo compressor t 2 t TVD = h TVD / c p 125 °C Performance of exhaust gas compressor 2 21,224 kW 2.5 Calculation of the performance of the CO2 high-pressure pump 100 bar Temperature CO 2 fluid T l 224 °K Condensation pressure p 1 7 bar Pressure CO 2 -Compressor pump P2 100.00 bar isentropic pump efficiency mass CO 2 or i,TVD 85.00% 37.71 kg / s Enthalpy CO 2 at the inlet high pressure pump h 1 = 224 °K, 7 bar (from material properties table) -192.00 kJ / kg s 1 = 224 °K, 7 bar (from material properties table) 2.73 kJ / kg Enthalpy CO 2 at the outlet of the high-pressure pump h 2 = 228 °K, 100 bar (from material properties table) -183.90 kJ / kg s 2 = 228 °K, 100 bar (from material properties table) 2.73 kJ / kg Performance with isentropic compression 305 kW Performance CO 2 -High-pressure pump 359 kW 2.6 Calculation f power of the gas turbine a Gas inlet temperature T 3 227 °K Pressure before turbine p 3 7.00 bar Pressure after turbine p 4 1.40 bar isentropic turbine efficiency or i,T, 90,00% c p, Ges = m N2 / m Ges * c p N2 + m AR / m Ges * cp Ar 1.032 kJ / kgK Isentropic exponent for mixture b (N 2 / Ar) KN2 / Ar 1,401969 Enthalpy N2 at the turbine inlet h 3 = c pN2 * t 3 234.32 kJ / kg Enthalpy N2 at turbine outlet h Tt = h 3 - the i,T * c pn" * T3 * [1-(p4 / p3) (k-1) / k -1] 156.4 kJ / kg Outlet temperature from the turbine t 2 T 4 = h TVD / c pN2 / Ar 151 °K Massenstrom N 2 + Ar 175.05 kg / s Turbine power -13,645.45 kW 2.7 Calculation g Power of the gas turbine b Gas inlet temperature T 3 240 °K Pressure before turbine p 3 1.40 bar Pressure after turbine p 4 1.00 bar isentropic turbine efficiency or i,T, 90,00% c p, Ges = m N2 / m Ges * c p N2 + m AR / m Ges * cp Ar 1.032 kJ / kgK Isentropic exponent for mixture b (N 2 / Ar) KN2 / Ar 1,401969 Enthalpy N2 at the turbine inlet h 3 = c pN2 * t 3 247.74 kJ / kg Enthalpy N2 at the turbine outlet h Tt = h 3 - the i,T * c pN2Ar" * T3 * [1-(p4 / p3) (k-1) / k -1] 227.2 kJ / kg Outlet temperature from the turbine t 2 T 4 = h TVD / c pN2 / Ar 220 °K Massenstrom N 2 + Ar 175.05 kg / s Gas turbine power b -3,589 kW 2.8 Calculation of cooling demand for CO2 condensation r = evaporation enthalpy CO 2 at 7 bar 335.60 kJ / kg Massenstrom CO 2 37.71 kg / s Cooling demand Condensation CO 2 12,657 kW 2.9 Calculation i Cooling of the gas mixture a in the multi-component heat exchanger Inlet temperature 298 °K C pGes 0.99 kJ / kgK h ein 296.5 kJ / kg Condensation temperature of CO 2 224 °K h aus 222.9 kJ / kg Δh 73.63 kJ / kg Total mass flow 213 kg / s Cooling requirement Cooling of the gas mixture a 15,666 kW 2.10 Calculation j Cooling demand condensation H2O in the multi-component heat exchanger x 1 Water content at 298 °K and 1 bar 0,020376 p s Saturation pressure at 298 °K 0.03171 bar p 2 Condensation pressure 7.00 bar x 2 Water content at p 2 and 298 °C = x 1 * (1-p s ) / (P 2 -P s ) 0,00283138 Mass flow exhaust gas 213 kg / s Condensate H 2 HE 0.6024 kg / s Heat of vaporization of water at 0°C 2,501 kJ / kg Cooling demand condensation H 2 O in the self-cleaning WT 1,507 kW 2.11 Calculation k cooling from stepwise 1. heating of the gas mixture b 1st stage - heating in the gas-refrigerant heat exchanger Inlet temperature gas mixture b 151,48 °K Outlet temperature gas mixture b 224,00 °K c p Gas mixture 2 1.03 kJ / kgK h ein = c p * T ein 156.4 kJ / kg h aus = c p * T aus 231.2 kJ / kg Δh 74.85 kJ / kg Mass of gas mixture 2 175 kg / s Heating gas mixture b 1st stage 13,103 kW 2nd stage heating in the heat exchanger component a Inlet temperature gas mixture b 224,00 °K Outlet temperature gas mixture b 240,00 °K c p Gas mixture 2 1.03 kJ / kgK h ein = c p * T ein 231.2 kJ / kg h aus = c p * T aus 247.7 kJ / kg Δh 16.52 kJ / kg Mass of gas mixture 2 175 kg / s Heating gas mixture b 2nd stage 2,891 kW 2.12 Calculation I Cooling from 2. Heating of the gas mixture b Inlet temperature gas mixture b 223 °K Outlet temperature gas mixture b 293 °K c p Gas mixture 2 1.03 kJ / kgK h ein = c p * T ein 230.2 kJ / kg h aus = c p * T 302.4 kJ / kg Δh 72.26 kJ / kg Mass of gas mixture 2 175 kg / s 2. Heating gas mixture b 12,649 kW 2.13 Calculation of cooling from heating of liquid CO2 Enthalpy CO 2 at the inlet of the self-cleaning heat exchanger h 2 = Table value 228 °K, 100 bar -183.90 kJ / kg Enthalpy CO 2 at the outlet of the self-cleaning heat exchanger h 3 = Table value 293 °K, 100 bar -46.00 kJ / kg CO flow 2 37.71 kg / s Warming CO 2 -5,201 kW List of reference symbols 1 Gas mixtures and substances 10 Exhaust gas in raw state with the components N2 , CO 2 , H 2 O, Ar, soot, dust 10a purified exhaust gas with the components N 2 , CO 2 , H 2 O, Ar 11a Gas mixture a, cooled with the components N 2 , CO 2 and Ar 11b Gas mixture a, compressed to the condensation pressure of CO 2 11c Gas mixture a, recooled 11d Gas mixture a, cooled to condensation temperature of CO 2 11e Gas mixture a, cooled with condensed CO 2 12a Gas mixture b - N 2 , Ar and CO 2 -Residues at condensation pressure 1st pressure stage 12b Gas mixture b without CO 2 -Remains on the 1st pressure stage 12c Gas mixture b partially expanded to the 2nd pressure stage 12d Gas mixture b partially expanded to the 3rd pressure stage 12e Gas mixture b relaxed at low temperature 12f Gas mixture b relaxed, moist at ambient temperature 13 CO 2 liquid at condensation pressure 13a CO 2 at supercritical pressure and low temperature 13b CO 2 at supercritical pressure and ambient temperature 14a H 2 O - Condensate from exhaust gas cooler a 14b H 2 O - Condensate from exhaust gas cooler b 14c H 2 O - Condensate from exhaust gas cooler c 15 coolants 16 Cooling water 17a Gas mixture c in the initial state 17b Gas mixture c cooled 18 Gas mixture d 19 Gas mixtures under pressure 19a Gas mixture e relaxed at low temperature 19b Gas mixture e expanded and heated 2 Components of the system 20 exhaust gas purification stage 21 Cooling tower 21a Exhaust gas cooler a 21b Exhaust gas cooler b 21c Exhaust gas cooler c 21d Cooling water pump a 21e Cooling water pump b 21f Cooling water pump c 21g cooling water circuit 22 exhaust gas turbocompressors 22a Exhaust gas turbocompressor 1st stage 22b Exhaust gas turbocompressor 2nd stage 23 multi-component heat exchangers 23a self-cleaning heat exchanger component 23b Engine flaps heat-emitting side of the self-cleaning heat exchanger component 23c Engine flaps heat-absorbing side of the self-cleaning heat exchanger component 23d Check valves heat-emitting side of the self-cleaning heat exchanger component 23e Check valves heat-absorbing side of the self-cleaning heat exchanger component 23f Heat exchanger component a for gas mixture b 23g heat exchanger component b for highly compressed CO 2 24a CO 2 -Capacitor 24b CO 2 -Condenser heat dissipating side 24c CO2 -Capacitor heat-absorbing side 24d CO 2 -separator 24e CO 2 -High-pressure pump 24f connection point a 24g connection point b 24h heat exchanger component of the heat absorbing side of the CO 2 -Capacitor 25a Adsorber a for CO 2 25b Adsorber b for CO 2 25c Changeover valve for adsorber a 25d Switching valve for adsorber a 25e Changeover valve for adsorber b 25f Changeover valve for adsorber b 26 a fan 26b Control valve a 26c check valve 27 Refrigeration circuit 27a Refrigerant / gas heat exchanger 27b Refrigerant / gas heat exchanger heat dissipating side 27c Refrigerant / gas heat exchanger heat absorbing side 27d Control valve b 27e refrigerant pump 28a Gas turbine a 28b Gas turbine b 28c multi-stage gas turbine 29 Connection for start-up operation with external N 2 29a Changeover valve start-up / control operation 29b Changeover valve start-up / control operation 3 Energy 30 Energy for exhaust gas compressors 30a Energy for exhaust gas compressor stage 1 30b Energy for exhaust gas compressor stage 2 30c energy for CO 2 -High-pressure pump 31a Heat dissipated exhaust gas cooler a 31b Heat dissipated exhaust gas cooler b 31c Heat dissipated exhaust gas cooler c 32a Work of the gas turbine a 32b Work of the gas turbine b 32c Work of the multi-stage gas turbine 4 pipe connections 40a Gas pipe a 40b Gas pipe b 40c gas pipe c 40d gas pipe d 40e gas pipe e 40f gas pipe f 40h gas pipe h 40i gas pipe i 40j gas pipe j 40k gas pipe k 41a CO 2 -pipe a 41b CO 2 -pipe b 41c CO 2 -pipe c 42a Nitrogen tube a 42b Nitrogen tube b 42c Nitrogen tube c 42d Nitrogen tube d 42e Nitrogen tube e 42f nitrogen tube f 42g nitrogen tube g 42h nitrogen tube h 42i nitrogen pipe i 42j Nitrogen tube j 42k nitrogen tube k 42l nitrogen tube l 42m nitrogen pipe 43a Cooling water line a 43b Cooling water line b 43c Cooling water line c 43d Cooling water line d 43e Cooling water line e 43f Cooling water line f 44a Drainage pipe a 44b Drainage pipe b 44c Drainage pipe c 45a Refrigeration pipe a 45b Refrigeration pipe b 45c Refrigeration pipe c 45d Refrigeration pipe d

Claims

[1] Process for turbo exhaust gas CO 2 -Separation from exhaust gas cleaned of particles with liquid CO 2 -Extraction at condensation pressure, comprising the steps: A. In process step A, the exhaust gas (10a) is cooled and the water vapor (14a) contained in the exhaust gas is condensed and separated, except for a residual portion of water vapor corresponding to the saturation pressure of the water vapor in the gas mixture; B. The remaining gas mixture a (11a) is heated in process step B to the temperature required for the condensation of CO 2 compressed to the required pressure and cooled down; C. In process step C, the gas mixture a (11c) is heated in the multi-component heat exchanger (23) to the condensation temperature of CO 2 cooled and the remaining portion of water vapor condenses or freezes in the self-cleaning heat exchanger component (23a) and is deposited there; D. In process step D, the CO 2 (13) in CO2 -condenser (24a) and separated from the exhaust gas in liquid form, whereby the remaining gas mixture b (12a) still contains a residual amount of CO 2 according to the saturation pressure of CO 2 in the gas mixture; K. In process step K, the gas mixture b (12a) is adsorbed from the residual CO 2 cleaned; L. In process step L, the gas mixture b (12b) is expanded to such an extent that the cold of the expanded gas mixture b (12c) is sufficient for the CO to be removed. 2 -Ethalation enthalpy in CO 2 -capacitor (24a,) is sufficient; M. In process step M, the CO 2 -Proportion in the gas mixture a (11d) in CO 2 -Capacitor (24a,) condenses N. Subsequently, in process step N, the cold of the gas mixture b (12c) f in the heat exchanger component a (23f) is used for the cooling requirement in the multi-component heat exchanger (23); O. In process step O, the heated gas mixture c (12c) is expanded to atmospheric pressure in the gas turbine b (28b) while performing work; P. In process step P, the cold expanded gas mixture b (12e) is heated in the self-cleaning heat exchanger component (23a), and the heated gas mixture b (12f) absorbs the deposited H 2 O from process step C and is discharged into the atmosphere after exiting the self-cleaning heat exchanger component (23a). [2] Process for turbo exhaust gas CO 2 -Separation from exhaust gas according to claim 1 characterized by that the following additional procedural steps are provided: F. In process step F, the CO separated in process step D 2 (13) and transferred to the CO2 -high pressure pump (24e), then the liquid CO 2 (13) with the CO 2 -High-pressure pump (24e) to the pressure required for underground storage and G. In process step G, the highly compressed CO 2 (13a) is heated in the heat exchanger component b (23g). [3] Device for turbo exhaust CO 2 -Capture of liquid CO 2 at condensation pressure from exhaust gas cleaned of particles, which has the following components: A. in the flow direction of the exhaust gas supplied to the device to the CO 2 -Separation of the components: • an exhaust gas cooler a (21a); • a single-stage or multi-stage exhaust gas compressor (22, 22a, 22b); • an exhaust gas cooler b (21b); • a self-cleaning heat exchanger unit (23a) connected via the engine flaps of the heat-emitting side (23b); • a CO 2-Condenser (24a) connected on the heat dissipating side (24b) and • a CO 2 -separator (24d); wherein the individual components are fluidically connected to one another in the order mentioned by pipes; B. In the flow direction of the CO 2 -separator (24d) separated CO 2 a connection point a (24f) for the downstream use of the captured CO 2 ; C. In the flow direction of the CO 2 -Separator (24d) separated gas mixture b (12a) the components: • a CO 2 -adsorber (25a, 25b); • a single-stage or multi-stage expansion turbine (28a, 28c); • the CO 2 -Capacitor (24a) connected on the heat-absorbing side (24c); • the heat exchanger component a (23f) • an expansion turbine b (28b); • the self-cleaning heat exchanger component (23a) connected via the motor flaps of the heat-absorbing side (23e) and • an outlet opening for the moist gas mixture b (12f) into the atmosphere; the individual components being fluidically connected to one another in the order mentioned by pipes. [4] Device for turbo exhaust CO 2 -Deposition according to claim 3 which additionally comprises the following components: D. In the flow direction of the CO 2 -Separator separated CO 2 the components: • A CO 2 -High pressure pump (24e) • a heat exchanger component (23e) for highly compressed CO 2 (13a) • A connection point b (24g) for the transmission of the highly compressed CO 2 into a downstream CO 2 -Storage or CO 2-Use; whereby the individual components are fluidically connected to one another by pipes in the order mentioned.

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