WO2021129925A1

WO2021129925A1 - Turbo exhaust gas co2 capture

Info

Publication number: WO2021129925A1
Application number: PCT/EP2019/086947
Authority: WO
Inventors: Wolfgang Kirchner; Hans Walter Kirchner
Original assignee: Kirchner Energietechnik GmbH
Priority date: 2019-12-23
Filing date: 2019-12-23
Publication date: 2021-07-01

Abstract

The invention relates to a method for turbo exhaust gas CO2 capture from exhaust gas that is purified of particles, using liquid CO2 extraction at condensation pressure, the method comprising the steps of: - cooling the exhaust gas to ambient temperature; - compressing the exhaust gas to CO2 liquefaction pressure and re-cooling to ambient temperature; - cooling the exhaust gas to CO2 condensation temperature; - separating gases by CO2 condensation and capture; - work-producingly expanding separated gases; - preparing the CO2 for subsequent storage or use. The invention also relates to a device for turbo exhaust gas CO2 capture of liquid CO2 at condensation pressure from exhaust gas that is purified of particles, and to a device for condensing CO2 in gas mixtures at a pressure between 6 and 15 bar.

Description

TURBO EXHAUST CO2 SEPARATION

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 and a device for condensing CO ₂ in gas mixtures at a pressure between 6 and 15 bar the preamble of claim 5.

The turbo exhaust gas CO ₂ separation serves to relieve the atmosphere of climate-damaging CO ₂ emissions from exhaust gases by removing the CO ₂ from the exhaust gases through condensation and the separated CO ₂ either subsequently being stored underground (CCS process - carbon capture and Storage) or any other use such as B. the use for CO ₂ - based plastics is supplied. The turbo exhaust gas CO ₂ separation process is one of the physical processes for separating CO ₂ from exhaust gases.

A 400 MW combined cycle power plant (gas and steam combined cycle power plant) emits approx. 1.2 million t CO ₂ per year (an equivalent coal-fired power plant emits 3.3 million t CO ₂ per year). On average, a forest area of 1 hectare can _{absorb approx. 4 t CO 2} per year. This one 400MW combined cycle power plant alone would therefore require an area of 300,000 hectares of forest to compensate for the emitted CO2S. The whole of Germany has a forest area of 1.2 million hectares, which would only be _{sufficient for CO 2} compensation for 4 of these power plants. The total energy consumption per year in Germany in 2017 was 2,591 TWh, 37.8% of which comes from renewable energy production. The remaining 1,600 TWh would require 457 400MW power plants to produce electricity. These would emit 550 (GuD) - 1,500 (coal) million t CO ₂ per year and that in Germany alone, which only accounts for 2.4% of world energy consumption. Electricity generation with renewable energy sources in Germany increased from 36% in 2017 to 37.8% in 2018. Energy production with fossil fuels cannot therefore be dispensed with in the medium to long term. In order to really mitigate or prevent a climate catastrophe, there is no alternative to the separation and underground storage of CO ₂ from combustion gases. This separation must be used with a minimum of Energy. This is the case with the turbo exhaust gas CO ₂ separation, for which a patent has been submitted here, which, depending on the type of exhaust gas, consumes 50-70% less energy than the previously investigated CCS processes.

The turbo exhaust gas CO ₂ separation is used in all processes in which exhaust gas is generated, such as B.

• in the separation of the CO ₂ in the exhaust gases from biomass power plants,

• the separation of the CO ₂ in the exhaust gases from combined cycle power plants,

• the separation of the CO ₂ in the exhaust gases from coal-fired power plants,

• the separation of CO ₂ in the exhaust gases from boilers,

• the separation of the CO ₂ in the exhaust gases from combustion engines,

• the separation of the CO ₂ in the exhaust gases from gas turbines and

• the separation of the CO ₂ in the exhaust gases from industrial burners.

An up-to-date overview of the state of research and development on the separation and storage of CO ₂ from exhaust gases is given in the technology _{report 2.3 CO 2} separation and storage - CCS "from Forschungszentrum Jülich on December 17, 2017. For CO ₂ separation from exhaust gases according to the According to this study, post-combustion processes are exclusively chemical absorption processes in research and development as well as membrane-based processes in a very early research stage (p. 9 of the report).

The main problems with chemical absorption are the decomposition of the solvents in the presence of oxygen and other foreign substances (e.g. dust), high rates of solvent degradation through reactions with sulfur dioxide or nitrogen oxide and the high energy consumption in the necessary regeneration of the solvent (p. 17 des Report).

In contrast to the previously used processes for CO ₂ separation and storage, physical processes have been considered uneconomical, since the physical processes for cryogenic CO ₂ separation considered up to now require too much energy due to high condensation pressures and low condensation temperatures used chillers and Compressor would be needed. In this consideration, however, energy recovery options and the storage of CO _{2 were} neglected.

For safety reasons, only storage tanks with a minimum depth of 800 m can be considered for underground storage. In order to be able to store it at such a depth, the CO ₂ must be in a supercritical state of aggregation due to the pressure prevailing there and for maximum utilization of the existing storage volume. A minimum pressure of 74 bar at 31 ° C is required for this. However, since all previously used CCS separation processes separate CO ₂ at normal pressure, it has to be compressed to 74 bar before storage. For this purpose, for example, an at least two-stage gas turbo-compressor cascade with an energy consumption of at least 16MW would be necessary _{for the CO 2} occurring in a 400MW combined cycle power plant. In all of the CCS processes investigated so far, _{almost as much energy is used to prepare the CO 2} for storage alone as in the complete "turbo exhaust gas CO ₂ separation process" for which a patent is applied.

In addition, there are system costs for the necessary turbo compressors, which _{amount to approx. 50% of the costs of a “turbo exhaust gas CO 2} separation” system.

The object of the invention of the turbo exhaust gas CO ₂ separation is therefore to develop a process for the complete, pure separation of CO ₂ from exhaust gases, which can be operated as a physical process without solvents and the problems associated therewith, and which is also clearly one requires less energy for the separation and processing for storage of the CO ₂ than the CCS processes currently being tested.

This object is achieved by a method for separating carbon dioxide with the method steps of claim 1.

Further advantageous method steps which optimize the method according to claim 1 emerge from dependent claim 2.

The object of the invention is also to provide a device for turbo exhaust gas CO ₂ separation from liquid CO2 ₂ at condensation pressure from exhaust gas that has been cleaned of particles to make available that is suitable for separating CO ₂ completely from waste gases without solvents and with little energy consumption

This object is achieved by a device for turbo exhaust gas CO ₂ separation of liquid CO ₂ at condensation pressure from exhaust gas that has been cleaned of particles according to claim 3.

An advantageous development of the device for turbo exhaust gas CO ₂ separation results from dependent claim 4.

Another object of the invention is to provide a device for the condensation of CO ₂ in gas mixtures with a pressure between 6 and 15 bar.

This object is achieved by a device for the condensation of CO ₂ in gas mixtures with a pressure between 6 and 15 bar with the features of claim 5.

Advantageous embodiments of the device for the condensation of CO ₂ in gas mixtures with a pressure between 6 and 15 bar are named on the basis of the dependent claims 6 to 8.

The following figures serve to illustrate embodiments of the invention. The individual figures show:

FIG. 1 method of turbo exhaust gas CO ₂ separation with CO ₂ removal in liquid form;

FIG. 2 method of turbo exhaust gas CO ₂ separation with CO ₂ removal at supercritical pressure;

FIG. 3 diagram of turbo exhaust gas CO ₂ separation with CO ₂ removal in liquid form;

FIG. 4 diagram of turbo exhaust gas CO ₂ separation with supercritical pressure extraction for underground storage; FIG. 5 method of turbo exhaust gas CO 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 removal and 2-stage exhaust gas compression;

FIG. 7 Scheme of the CO ₂ condensation according to an embodiment with direct cooling and a single-stage expansion turbine;

FIG. 8 shows a diagram of the CO ₂ condensation according to a further embodiment with direct cooling and a multi-stage expansion turbine;

FIG. 9 Scheme of the CO ₂ condensation according to a further embodiment with indirect cooling.

The turbo exhaust gas CO ₂ separation process uses the following process steps to separate CO ₂ from exhaust gas that has been cleaned of particles:

• Exhaust gas cooling to ambient temperature

• Flue gas compression to the CO ₂ condensing pressure with recooling to ambient temperature

• Flue gas cooling to the CO ₂ condensation temperature

• Gas separation through CO ₂ condensation and separation

• Work-performing expansion of decomposed gases

• Preparation of the CO ₂ for subsequent storage or use.

The turbo exhaust gas CO ₂ separation is characterized in that turbo machines and heat exchangers are used for the compression and cooling of the exhaust gases. The energy requirement is limited by the fact that the energy initially expended for the compression of the exhaust gas is partially recovered in later process steps by expansion of the decomposed gases in gas turbines and, at the same time, the cooling required in the process is generated by the expansion of the decomposed gases. Energy is lost between compression and expansion through the internal losses in the turbo compressors and gas turbines, but 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.

The term "turbo exhaust gas CO ₂ separation" was developed for the process from the central importance of _{turbo machines in separating CO 2} and to differentiate it from chemical CO _{2 separation processes.}

The turbo exhaust gas CO ₂ separation 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 separation with CO ₂ removal in liquid form at condensation pressure,

• Process variant 2: Turbo exhaust gas CO ₂ separation with CO ₂ removal at supercritical pressure for underground storage.

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 manner in order to store the huge amounts of CO ₂ that arise underground and to completely avoid climate-damaging CO ₂ power plant emissions into the atmosphere in the future.

Power stations operated with fossil fuels would carbon neutral in biomass power stations would climate positive, since the biomass is cut off during growth of the atmosphere of CO _2.

The process of global warming through atmospheric CO ₂ is reversed!

Description of variant 1 (Figures 1 and 3)

The turbo exhaust gas CO ₂ separation with removal of the CO ₂ in liquid form is divided into the following process steps:

1. Pre-stage exhaust gas cleaning

The exhaust gas 10 to be treated must be cleaned of particles such as dust, fly ash and soot particles _{before the turbo exhaust gas CO 2 separation.} The Particulate pollution of the exhaust gas 10 is very much dependent on the upstream combustion process.

Depending on the type and intensity of the particle load, different filter and separation techniques are used in the exhaust gas cleaning stage 20, such as B. electrostatic precipitators, centrifugal separators, fabric filters or scrubbers.

In accordance with the requirements of the venting devices of turbomachinery, very thorough removal of the 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 gas CO ₂ separation. However, this is not part of the procedure, so an in-depth description of exhaust gas cleaning is not required here. Process step A

In method step A, the exhaust gas 10a which has been cleaned of particles is cooled in the exhaust gas cooler a 21a. A large part of the water vapor contained in the exhaust gas condenses and is deposited as condensate 14a.

The temperature at which the exhaust gas enters the turbo exhaust gas CO ₂ separation has a wide temperature range depending on the upstream combustion process (e.g. 50 ° C for an engine BFIKW and several hundred ° C behind a single-stage one Gas turbine), so that the amount of heat that has to be dissipated in process step a is very different.

The cooling in the exhaust gas cooler a 21 a takes place with cooling water and is limited by the temperature of the available cooling water 16, which as a rule has to be obtained by means of a cooling tower 21. At some locations, cooling water from the sea or rivers may also be available. With this exhaust gas cooling, depending on the location and time of year, the exhaust gas can be cooled to a temperature range between +5 ° C and +30 ° C. 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 ₂ O, is compressed in the exhaust gas turbo compressor 22 to a pressure above 5.16 bar and then cooled back in the exhaust gas cooler b 21b. When using cooling water 16, the temperature range described above between +5 ° C and +30 ° C can be achieved again during re-cooling. The majority of the water vapor contained in the exhaust gas condenses and is deposited as condensate 14b.

In the exhaust gas turbo compressor 22, the level of compression must be selected to be so high that the required cold for the process can be generated when the gas mixture b 12 is expanded and heated. The calculation carried out for several exemplary embodiments showed that compression to 6 to 15 bar is sufficient for this.

With higher compression, the CO ₂ can subsequently be liquefied at higher temperatures, but the higher energy expenditure required for the additional compression of the exhaust gas worsens the economic efficiency.

Over 90% of the energy required for the turbo exhaust gas CO ₂ separation is used for exhaust gas compression. A lower energy expenditure for the exhaust gas compression can be achieved through a multi-stage compression with intermediate cooling. The energy required to compress the exhaust gas decreases with the number of compression stages. In return, a higher investment is required for the additional compression stages.

In the single-stage compression in FIGS. 3 and 4, the drive energy 30 must be used for the compressor 22. In the case of a two-stage compression in FIG. 5, the drive energy is 30a for the 1st compressor stage 22a and the drive energy for the 2nd compressor stage 22b 30b required. The same applies analogously if it is divided into even more compression levels. The sum of the drive energy 30 a, 30 b of the two-stage compression is smaller than the drive energy (30) of the single-stage compression.

When designing the turbo CO ₂ separation for specific applications, a project-specific optimum can be determined from the reduced energy costs with several compressor stages and the resulting increase in investment costs by means of a profitability calculation. Process step C

The compressed and recooled gas mixture a 11b is cooled in process step C in the multicomponent heat exchanger 23 to the condensation temperature of the CO ₂ .

Exiting the exhaust gas cooler (s) 21 as saturated, moist exhaust gas, the exhaust gas 11c still has a considerable water content, which at 25 ° C. and 7 bar is approx. 2.8 g per kg of gas.

Therefore, when the exhaust gas 11c is cooled to below the freezing point of water, a self-cleaning heat exchanger component 23a is required to cool the exhaust gas, because during this cooling the water vapor still contained in the gas mixture 11c condenses or freezes out, deposits on the walls of the heat exchanger component 23a and without cleaning - Measures the heat exchanger component 23a would clog. In the self-cleaning heat exchanger component 23a, by periodically switching the flow with the motor flaps 23b, 23c and the non-return flaps 23d, 23e, the ice deposited on the walls of the heat exchanger and the condensed water is absorbed by the gas mixture b 12f discharged into the atmosphere and the heat exchanger so again completely cleaned.

Self-cleaning heat exchangers are known components from air separation plants. Basically, for the turbo exhaust gas CO ₂ - Separation of all types of self-cleaning heat exchangers known from air separation plants are suitable. For example, cross-flow counterflows, stone-filled regenerators with built-in pipe coils or recuperators in compact design (often referred to as reversing exchangers).

The heat exchanger components of the heat-emitting side and the heat-absorbing side and other heat exchanger components are integrated in the self-cleaning multi-component heat exchangers, such as a heat exchanger 23f - e.g. B. as a built-in coil - for the heat absorption of the gas mixture b 12c after the CO ₂ condenser 24a.

In the self-cleaning multi-component heat exchanger 23, the following amounts of heat must be removed from the gas mixture a 11c:

• the enthalpy difference of the gas mixture a 11c from the outlet temperature from the last exhaust gas cooler 21c to the condensation temperature of the CO ₂ and

• the enthalpy of evaporation of the condensing water vapor fraction.

The cold 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 is expanded to atmospheric pressure in the gas turbine b 28b, in the self-cleaning heat exchanger component 23a. Process step D

In process step D, the condensation and separation of the CO _{2 takes place} from the exhaust gas stream 11d, which is cooled to the separation temperature and pressure and compressed. The condensation is carried out in CO ₂ in the CO ₂ - capacitor (24b). 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 interests of energy efficiency, works exclusively with cold from the expansion of the gas mixture b 12c.

The condensation temperature of the CO ₂ is relatively close to the triple point of the CO _2. At 7 bar condensation pressure, the condensation temperature of the CO _{2 is} 224 ° K, only 7.5 ° K above the 216.5 ° K at the triple point. The temperature of the exhaust gas 11 d may drop at any point in the CO ₂ condenser 24a below the sublimation temperature of the CO _2, otherwise the heat exchanger and pipes would become clogged. There are therefore high demands on the temperature control of the CO ₂ condenser 24a.

This temperature requirement is achieved when the heat-absorbing gas mixture b 12c in a multi-stage expansion turbine 28c is only expanded to such an extent in each expansion stage that the turbine outlet temperature is below the sublimation temperature of the CO _{2 by} a maximum of the temperature difference in the heat exchanger.

When the single-stage expansion turbine 28a is used, the turbine outlet temperature is significantly below the sublimation temperature of CO ₂ . In the calculation example attached, the outlet temperature of the gas mixture b 12c from the expansion turbine a 28a is 156 ° K and is thus well below 216.5 ° K. For temperature control on the heat-absorbing side of the CO ₂ condenser, there are 2 options for single-stage expansion:

• Direct cooling of the CO ₂ condenser by mixing the cold to the CO ₂ condenser recirculated gas mixture with the heated CO ₂ from the condenser upcoming gas mixture with the aid of a control valve 26b. The required mass flow of the gas mixture is conveyed through the CO ₂ condenser 24a by the speed-controlled fan 26a. An exemplary embodiment for the direct cooling of the CO ₂ condenser is shown in FIG. With the indirect cooling of the CO ₂ condenser 24a, the expansion cold of the gas mixture b 12c in the refrigerant / gas heat exchanger c 27a is transferred to the refrigerant c 15, which is carried out in the refrigeration circuit 27 by regulating the refrigerant pump 27e and the control valve 27d with a precisely regulated temperature the CO ₂ condenser 24a is pumped and there provides the cold necessary for the evaporation enthalpy to be removed in the gas mixture a 11 d. At temperatures between 150 ° K and 230 ° K in the indirect cooling circuit, only fluids with a low melting point, such as. B. propane with a melting point of -187.7 ° C, iso-butane with a melting point of -159 ° C or a gas such as. B. N ₂ can be used as a coolant.

After the CO ₂ condensation, the separation into the liquid CO ₂ 13 and the remaining gas mixture b 12a takes place in the CO _{2 separator 24c.} Method step K

The gas mixture b 12a with the constituents N ₂ and Ar 13a coming from the CO ₂ _{separator 24c contains a CO 2} component corresponding to the saturation pressure of the CO ₂ at the temperature in the gas mixture b 12a, which or condenses out upon further cooling of the gas mixture b 12a would freeze out.

This CO ₂ fraction is therefore removed from the gas mixture b 12a with the aid of CO ₂ adsorbers 25a, 25b. Usual CO ₂ adsorbers work as

Molecular sieve adsorber with zeolites as adsorption material in pendulum mode. Two adsorbers are used for this. While one adsorber is alternately in operation and _{adsorbing CO 2} , the second adsorber is regenerated with the aid of a purge gas. The requirement for the flushing gas is that it must be dry, free of carbon dioxide and hydrocarbons and that it must be heated to approx. 100 ° C. In the case of turbo exhaust gas CO ₂ separation, the gas mixture b 12e is suitable as the flushing gas. Waste heat can be used to heat the gas, e.g. B. the heat of the exhaust gas 11 b after exiting the exhaust gas compressor 22. 7. Process step L

In process step L, the cleaned gas mixture b 12b is expanded while performing work in the gas turbine a 28a to such an extent that the coldness of the expanded gas mixture b 12c is _{sufficient for the evaporation enthalpy to be removed during the CO 2} condensation (process step M).

8. Method step M

In method step M, the expansion cold of the gas mixture b is used to condense the CO ₂ content in the gas mixture a in the CO ₂ condenser 24a.

9. Process step N

Subsequently, in method step N, the coldness of the gas mixture b 12c is used for the heat transfer in the heat exchanger component 23f, which is integrated in the multicomponent heat exchanger 23, for the refrigeration requirement in the multicomponent heat exchanger 23.

10. Process step O

In method step O, the heated gas mixture b 12c is expanded to atmospheric pressure while performing work in the gas turbine b 28b.

11. Process step P

In method step P, the cold expanded gas mixture b 12g is heated in the multicomponent heat exchanger 23 and the heated gas mixture b 12g is used for backwashing the self-cleaning heat exchanger component 23a. _{When heated, the gas mixture b absorbs the H 2} O which has condensed or frozen out as it passes through the self-cleaning heat exchanger component 23a. Then the moist gas mixture b 12g is discharged into the atmosphere _{without any climate-damaging CO 2.} Description of variant 2 (Figures 2 and 4)

In turbo exhaust gas CO ₂ separation with CO ₂ removal at supercritical pressure, exhaust gas that has been cleaned of particles is treated as follows.

1 . Process steps A and B

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 removal of the CO ₂ at condensation pressure.

2. Process step C

Process step C also largely corresponds to process variant 1, but the heating of the supercritically compressed CO ₂ 13h in the heat exchanger component 23g, which is also integrated in the multi-component heat exchanger 23, is used to provide the required cold.

3. Process step D

In method step D, the CO _{2 is} condensed and separated, as in the case of liquid CO ₂ removal at condensation pressure, but passed on to a CO ₂ high-pressure pump 24e for further treatment.

4. Process step F

In method step F, the liquid CO ₂ 13 is compressed with the CO ₂ high-pressure pump 24e to the supercritical pressure required for underground storage and then passed into the heat exchanger component 23g. In terms of energy, the compression of a substance in the liquid state is particularly advantageous, since the energy expenditure required in the liquid state for the compression of liquids is many times smaller than that for the compression of gases. How far it has to be compacted depends on the pressure that is required for storage in the respective storage facility. As the compression pressure increases, so do the demands on the transport _{equipment - with the very large amounts of CO 2 produced} by power plants, CO ₂ pipeline transport is an appropriate technique. The compression pressure of 100 bar selected in the calculation _{example for the CO 2} can be seen as cost-consciously realizable according to the state of the art, since this pressure is also used in high-pressure transport lines for natural gas.

5. Method step G

In method step G, the supercritical CO ₂ 13a in the heat exchanger component b 23g is heated to ambient temperature. After heating in the heat exchanger component b 23g, the highly compressed CO ₂ l3b is removed from the turbo exhaust gas CO ₂ separation and z. B. transported to an underground storage facility. _{With the compression pressure for the CO 2} of 100 bar selected in the calculation example, the specific volume at 290 ° K 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 greater than 800 m (minimum storage depth for CO ₂ final storage) and the pressure prevailing at this depth to be able to be deposited and to use the available storage volume to the maximum.

6. Process steps K, L, M, N, O and P

The gas mixture b 12a separated after CO ₂ condensation and CO ₂ separation in process step D is used in the turbo exhaust gas CO ₂ separation with CO ₂ removal at supercritical pressure in process steps K, L, M, N, O and P treated identically as in process variant 1.

Advantages of CO ₂ extraction at supercritical pressure

The compression and heating of the liquid CO ₂ separated at condensation pressure and low temperature in variant 1, to supercritical storage pressure and heating to ambient temperature in variant 2 is the decisive step in order _{to be able to store the CO 2} underground and the exhaust gas from the atmosphere keep away. Due to the heat absorption of the supercritical CO ₂ 13h in the heat exchanger component 23g, additional compressor work 30 can be saved compared to variant 1.

Apparatus for the Turbo-Abqas-CO ₂ -Abscheidunq

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 adsorbers.

Apparatus 1 for the turbo Abqas-CO ₂ Abscheidunq with CO ₂ demoulding system liquid at condensing pressure

In the apparatus for turbo exhaust gas CO ₂ separation with CO ₂ removal in the 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 forwarded to the downstream exhaust gas compressor 22 through the exhaust gas pipe b 40b. To cool the exhaust gas, the exhaust gas cooler is connected to the pipelines of the cooling water circuit 21g, on the flow side to the cooling water line a 43a and on the return side to the cooling water line b 43b. Before exiting the exhaust gas cooler 21a, a separator integrated in the exhaust gas cooler prevents the water condensed in the exhaust gas cooler from being carried on 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.

The exhaust gas fed to the exhaust gas compressor 22 via the exhaust gas duct b 40b is there _{compressed to the condensation pressure of the CO 2.} The exhaust gas is passed on from the exhaust gas compressor 22 into the gas cooler b 21b through 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 flow side with 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 in the exhaust gas cooler prevents the Water condensed in the exhaust gas cooler is carried on 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.

From the outlet from 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.

Before the self-cleaning heat exchanger component 23a, the gas pipe d 40d is divided by a T-piece into two parallel lines, of which one of the lines is used by the exhaust gas for the outward journey and the other line is used by the line remaining _{after the CO 2 separation} Gas mixture b 12e is used as a path in the opposite direction. For switching between the gas paths, on the heat-emitting side of the self-regulating heat exchanger component 23a, two motor flaps 23b actuated by the control system are installed behind the T-piece in the parallel lines of the gas mixture a. In the parallel lines of the gas mixture b flowing in the opposite direction, two motor flaps 23c operated by the control are also installed on the heat-absorbing side, before the parallel line routing is brought together again by installing a T-piece. On the cold side of the self-cleaning heat exchanger component 23a, two non-return valves 23d are built into the parallel lines of the gas mixture a 11 d before the parallel lines for the gas mixture a are brought together again via a T-piece. The nitrogen pipe f 42f for the gas mixture b 12e flowing in the opposite direction is divided on the cold side of the self-cleaning heat exchanger component by a T-piece between the two parallel gas lines and here too two non-return valves 23e are installed in the parallel gas lines for the gas mixture b.

In the self-cleaning heat exchanger component 23a, heat exchanger surfaces are arranged between the two gas mixture a 11c and gas mixture b 12e flowing in the opposite direction, which enable the heat transfer between the gases and prevent material mixing. In the version with 2 stone-filled regenerators, which is also possible for the self-cleaning heat exchanger component 23a, the regenerators are in pendulum mode in Direction of the gas mixture to be broken down a 11c or in the opposite direction when flowing through the gas mixture b 12e operated with periodic switching.

To cover the cooling requirement in the multicomponent heat exchanger 23, the heat exchanger component a 23f is installed for the cold utilization of the gas mixture b 12c. On the cold side, the heat exchanger component a 23f is connected to the nitrogen pipe d 42d and on the warm side to the nitrogen pipe e 42e.

The gas mixture a 11 d recombined in the T-piece is passed on through the gas pipe g 40 g to the CO ₂ condenser 24 a and there connected to the heat-emitting side 24 b. At the outlet of the CO ₂ condenser 24a, the CO ₂ portion is condensed in the gas mixture a 11e and the gas mixture a 11e is _{fed into the CO 2} separator 24d via the gas pipe h 40h. The condensed CO ₂ is withdrawn from the CO ₂ separator 24d via a connection on the sump side and fed to the subsequent use _{via the CO 2 pipe 41a.}

The gas mixture b 12a, which _{remains after separating the CO 2} , is removed from the CO ₂ separator via a connection at the top and passed through the nitrogen pipe a 42a into the CO ₂ adsorbers 25a, 25b, which act as molecular sieve adsorbers with zeolites _{separate the remaining CO 2} present in the gas mixture b 12a as adsorption material in pendulum operation. The gas mixture b 12a flows through the two switchover valves 25c or 25e installed in front of the adsorbers and actuated by the control, which together with the two switchover valves 25d or 25f installed behind the adsorbers and actuated by the control ensure that the two adsorbers are used alternately.

From the CO ₂ adsorber 25a, 25b, the gas mixture b 12b is passed through the nitrogen pipe b 42b to the gas turbine a 28a, where it is expanded while performing work.

From the outlet from the gas turbine a 28a, the gas mixture b 12c is guided through the nitrogen pipe c 42c to the heat-absorbing side 27c of the refrigerant / 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 of the refrigeration circuit 27. The cold from the refrigerant / gas heat exchanger 27a to the CO ₂ condenser 24a is transported via the cold pipes a 45a, and the temperature and flow rate of the refrigerant 15 is exactly for the refrigerant requirement in the CO _{2 through the control valve b 27d and the control of the refrigerant pump 27e} -Condenser 24a. The return flow of the coolant 15 from the CO ₂ condenser 24a to the coolant / gas heat exchanger 27a takes place through the cold pipe b 45b.

The gas mixture b 12c is led from the outlet from the refrigerant / gas heat exchanger 27a through the nitrogen pipe d 42d to the connection to the heat exchanger component a 23f, which is built into the multi-component heat exchanger 23. After being heated in the heat exchanger component 23f, the gas mixture b 12c is guided from the outlet from the heat exchanger 23e through the nitrogen pipe e 42e to the inlet into the gas turbine b 28b, where it is expanded while performing work.

The expanded gas mixture b 12e is passed from the outlet from 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 subsequently, as described above, alternately guided on the alternating gas paths through the self-cleaning heat exchanger component 23a. In the self-cleaning heat exchanger component 23a, the heat exchange already 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 into the atmosphere via the nitrogen pipe g 42g.

Apparatus 2 for the turbo exhaust gas CO ₂ Abscheidunq with CO ₂ at supercritical pressure demoulding system

The structure of the apparatus 2 coincides with the structure of apparatus 1 up to the sump-side exit of the CO ₂ from the CO ₂ separator 24d via the CO ₂ pipe a 41 a, with the addition that the multicomponent heat exchanger 23 also has the Heat exchanger component b 23g for heating the supercritically compressed CO _{2 is} installed.

In apparatus 2, the condensed CO ₂ 13 is removed from CO ₂ separator 24d via a sump-side connection and transported via CO ₂ pipe 41a to CO ₂ high-pressure pump 24e, where it is compressed to the supercritical pressure required for underground storage.

_{The CO 2} 13a, which is compressed to supercritical pressure in the CO ₂ high-pressure pump 24e _{, is fed into the heat exchanger component b 23g via the CO 2} pipe b 41b, flows through the heat exchanger component b 23g and absorbs heat in the process. _{The CO 2} 13b heated in the heat exchanger 23g is passed through the CO ₂ pipe c 41c to the connection point b for the further transport of _{CO 2 24g.}

The structure of the apparatus 2 for treating the gas mixture b 12a, which is removed from the CO ₂ _{separator 24d after the CO 2 has been separated off} via a connection at the top, corresponds completely to the structure in apparatus 1.

Apparatus 1 to 2 for the turbo exhaust gas CO ₂ -Abscheidunq with sulfur-containing

Fuels

When fuels containing sulfur are burned, the exhaust gas contains SO2 and SO3, which react to form sulfuric acid and sulfuric acid when the water vapor condenses in the exhaust gas.

The acid dew point of fuels containing sulfur is in the range of 120 ° to 150 ° C. This temperature is fallen below in the exhaust gas heat exchanger a 21a and in the exhaust gas heat exchanger b 21b, 21c.

Falling below this means that highly corrosive sulfuric acid condenses out and attacks the wall. Therefore, when using fuels containing sulfur, 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)). When treating sulfur-containing exhaust gases, the condensate of the exhaust gas heat exchangers a 14a-14c is acidic, which must also be taken into account for subsequent disposal or use.

SO2 and SCh gas constituents that have not reacted with the condensing water vapor condense when the phase boundary gas / liquid 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 14c.

Apparatus 3 CO ₂ condensation system with direct nitrogen cooling and single-stage expansion turbine

The CO ₂ condensation system with direct cooling and a single-stage expansion turbine is an apparatus with which CO _{2 is} condensed and separated in gas mixtures. The CO ₂ condensation system with direct cooling and a single-stage expansion turbine can be used for separating CO ₂ from gas mixtures of all kinds.

The CO ₂ condensation begins with the supply of the gas mixture c 17a, which has been cleaned of particles, into the heat-emitting side of the CO ₂ condenser 24b. In the heat-emitting side of the CO ₂ condenser 24b, the heat of condensation of the CO _{2 is} withdrawn from the gas mixture c 17a. After the CO ₂ condensation, the gas mixture c 17b is transported through the gas pipe i 40i into the CO ₂ separator 24d.

At the top, the CO ₂ separator has a connection for the further transport of the _{residual gas 18 remaining after the CO 2} separation. On the sump side, the CO ₂ separator 24d has a connection point a 24f for the further transport of the liquid CO ₂ 13.

In the case of direct cooling with a single-stage expansion turbine, the expanded cold gas mixture 19a is connected to the nitrogen tube 42h on the cold side and to the nitrogen tube i 42i on the warm side _{on the heat-absorbing side of the CO 2 condenser 24c.} The cold source is the pressurized cold gas or gas mixture e 19. The use of nitrogen is particularly suitable as a gas or gas mixture because of the low condensation temperature.

The pressurized cold gas or gas mixture e 19 is fed to the gas turbine a 28a, expanded there and transported as a _{gas mixture e 19a cooled to below the condensation temperature of CO 2} through the nitrogen tube h 42h into the heat-absorbing side of the CO ₂ condenser 24c. By means of the control valve a 26b and the control of the fan 26a, the temperature and flow rate of the gas mixture e 19a is conditioned precisely for the refrigeration requirement and the permissible temperatures in the CO ₂ condenser 24a. After heating in the CO ₂ condenser, the gas mixture e 19b is led out of the CO ₂ condensation system with direct cooling and a single-stage expansion turbine through the nitrogen pipe i 42i.

Apparatus 4 CO ₂ condensation system with direct nitrogen cooling and multi-stage expansion turbine

The CO ₂ condensation system with direct cooling and a multi-stage expansion turbine is an apparatus with which CO _{2 is} condensed and separated in gas mixtures. The CO ₂ condensation system with direct cooling and a multi-stage expansion turbine can be used for separating CO ₂ from gas mixtures of all kinds.

The CO ₂ condensation begins with the supply of the gas mixture c 17a, which has been cleaned of particles, into the heat-emitting side of the CO ₂ condenser 24c. In the heat-emitting side of the CO ₂ condenser 24c, the heat of condensation of the CO _{2 is} withdrawn from the gas mixture c 17a. After the CO ₂ condensation, the gas mixture c 17b is transported through the gas pipe i 40i into the CO ₂ separator 24d. At the top, the CO ₂ separator has a connection for the further transport of the _{residual gas 18 remaining after the CO 2} separation. On the sump side, the CO ₂ separator 24d has a connection point a 24f for the further transport of the liquid CO ₂ 13. In the case of direct cooling with a multi-stage expansion turbine, the heat-emitting side of the CO ₂ condenser 24c is composed of several individual heat exchanger components 24h. In each of these individual heat exchanger components 24, the expanded cold gas mixture of the respective expansion stage is introduced at a temperature takes place in which no sublimation nor of the CO ₂ in the CO ₂ -Kondensationsanlage.

The advantage of this direct cooling with a multi-stage expansion turbine, compared to direct cooling with a single-stage expansion turbine and indirect cooling, is that no regulating elements are required. The cold source of the CO ₂ condensation system with direct cooling and a multi-stage expansion turbine is the pressurized cold gas or gas mixture e 19.

The multi-stage gas turbine 28c is after each expansion stage via a nitrogen pipe k 42k with the cold side of the individual heat exchanger 24d and through the nitrogen pipe i 42i the gas mixture e is passed through a gas pipe I 42I into the next stage of the multi-stage expansion turbine 28c. After the last expansion stage, the expanded gas mixture e is led out through the nitrogen pipe m from the 42m from the CO ₂ condensation system with direct cooling and a multi-stage expansion turbine.

Apparatus 5 CO ₂ condensation system with indirect cooling

The CO ₂ condensation system with indirect cooling is an apparatus with which CO _{2 is} condensed and separated in gas mixtures. _{The CO 2} condensation system with indirect cooling can be used to separate _{CO 2} from gas mixtures of all kinds.

The CO ₂ condensation begins with the supply of the gas mixture c 17a, which has been cleaned of particles, into the CO ₂ condenser 24. The CO ₂ condenser 24 is a heat exchanger in which, with indirect cooling, on the heat-absorbing side of the CO ₂ condenser 24a, the refrigeration circuit 27 is connected to the refrigeration line 45c on the flow side and the cold pipe 45d on the return side. After the CO ₂ condensation, the gas mixture c 17b is transported through the gas pipe i 40i into the CO ₂ separator 24d.

The cold source is the pressurized cold gas or gas mixture e 19. The use of nitrogen is particularly suitable as a gas or gas mixture because of the low condensation temperature.

The pressurized cold gas or gas mixture e 19 is fed to the gas turbine a 28 a, expanded there and transported as a gas mixture e 19 a _{cooled to below the condensation temperature of CO 2} through the nitrogen tube h 42 h into the refrigerant / gas heat exchanger 27 a. After heating in the refrigerant / gas heat exchanger 27a, the gas mixture e 19b is led out of the CO ₂ condensation system with indirect cooling.

In the refrigerant / gas heat exchanger 27a, the coldness of the gas mixture e 19a is transferred to the refrigerant 15. The heat-emitting side of the coolant / gas heat exchanger 27b is connected to the pipes 45c and 45d of the refrigeration circuit 27. The cold from the refrigerant / gas heat exchanger 27a to the CO ₂ condenser 24a is transported via the cold pipe g 45j, and the temperature and flow rate of the refrigerant 15 is exactly matched to the refrigerant requirement in the CO _{2 through the control valve b 27d and the control of the refrigerant pump 27e} - Conditioned capacitor 24a. The return flow of the refrigerant 15 from the CO ₂ condenser 24a to the refrigerant / gas heat exchanger 27a takes place through the cold pipe k 45k.

The advantage of the condensation system with indirect cooling, compared to the condensation systems with direct cooling, that the volume and power control for the flow through the CO ₂ condenser 24a with the Refrigeration circuit 15 is much simpler than the volume and power regulation of the gas mixture e 19.

Economy and energy consumption of the turbo exhaust gas CO ₂ separation

As explained above, the turbo exhaust gas CO ₂ separation can be used in very many different combustion processes, so that generally valid statements on costs, economy and energy consumption are not possible. Rather, the economic and energetic effects must be examined and calculated individually for each application.

The turbo exhaust gas CO ₂ separation, like any other method for CO ₂ separation, requires the use of energy for the separation of the CO ₂ . Depending on the use, additional energy consumption is required for the storage or further processing of the CO ₂ , which, as already mentioned at the beginning, is _{negligibly small with the turbo exhaust gas CO 2} separation compared to the other CCS separation processes.

In the context of this patent application, the use of the turbo exhaust gas CO ₂ separation for the treatment of exhaust gases from a modern, highly efficient combined cycle power plant is calculated as an example.

The calculation example for the combined cycle power plant assumes around 400 MW electrical output and an electrical efficiency without CO ₂ separation of 60% and is attached as an annex. When the CO _{2 is} compressed to a supercritical pressure of 100 bar, the electrical efficiency of the combined cycle power plant in the calculation example drops from 60% to around 56%.

In the event that the CO _{2 is} withdrawn at an evaporation pressure of approx. 6 bar, the electrical efficiency of the combined cycle power plant drops a little less, from 60% to around 57%.

Generally valid statements on the economic effects of the CO ₂ emissions saved _{with the turbo exhaust gas CO 2} separation are difficult, since the certificates trading currently practiced has market-dependent prices. The current The law on CO2 taxation provides for a CO ₂ tax of 25 € / t CO ₂ from 2021 with an increase to 55 € / t CO ₂ in 2025.

In the following, an example calculation is carried out on the assumption that the power plant's revenues for electricity sales are 45 € / MWh (mean price 2018). The sales revenue for electricity lost through the use of turbo exhaust gas CO ₂ separation can thus be calculated as follows:

Electricity revenue per hour 45 € / MWh

Output 400 MW combined cycle power plant without turbo exhaust gas CO ₂ -

Deposition 403 MW

Output 400 MW combined cycle power plant with turbo exhaust gas CO ₂ separation 372 MW

Electricity sales per hour without turbo exhaust gas CO ₂ separation € 18,135

Electricity sales per hour with turbo exhaust gas CO ₂ separation € 16,740

Loss of sales revenue per hour € 1,395

At a tax rate of 25.00 € / t from 2021, the _{tax savings achieved through turbo exhaust gas CO 2} separation can be calculated as follows:

Saving 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

The comparison of reduced sales proceeds with saved CO ₂ tax results in savings for the 400MW combined cycle power plant of € 14.6 million per year if the power plant is operated with turbo exhaust gas CO ₂ separation. Taking into account the high investment and operating costs of the turbo exhaust gas CO ₂ separation system and the additional costs incurred due to the underground storage, the comparison shows the enormous economic potential of turbo exhaust gas CO ₂ separation.

In addition to the economic considerations, the enormous ecological advantage for reducing the CO ₂ concentration in the atmosphere by • avoiding further climate-damaging CO ₂ emissions or • The reversal of climate damage caused by biomass power plants through turbo exhaust gas CO ₂ separation and underground storage are taken into account.

Calculation example

0. Explanation of the calculation example of the turbo exhaust gas CO ₂ separation

A combined cycle power plant with around 400 kW electrical output, an electrical efficiency of 60% and operation with the fuel natural gas H is used as a calculation example.

In the calculation, it is assumed, for a better overview, that the compressors and turbines of the turbo exhaust gas CO ₂ separation are arranged on a shaft with the combined cycle turbines. If this is not the case, the following results must be corrected for the electrical efficiency of the motors and generators.

The calculation is made for the application that the CO _{2 is} withdrawn from the process at supercritical pressure for underground storage,

1. Compilations

1.1 Energy balance and loss of efficiency of the combined cycle power plant with turbo exhaust gas CO ₂ separation and CO ₂ removal at 100 bar

1 .2 Balance of the CO ₂ condenser

1.3 Balance of the multi-component heat exchanger

2. Calculations

2.1. Calculation a - Determination of exhaust gas mass flow and exhaust gas composition

28

Calculation of the exhaust gas mass flow

2.2. Calculation b - Determination of the isentropic exponent for the gas mixtures

2.3 Calculation c performance of the exhaust gas compressor - 1. step

2.4 Calculation of the performance of the exhaust gas compressor - 2nd stage

2.5 Calculation of the performance of the COa high-pressure pump 100 bar

2.6 Calculation f power of the gas turbine a

2.7 Calculation g power of the gas turbine b

2.8 Calculation of the h cooling requirement for the condensation of the CO ₂

2.9 Calculation i cooling of the gas mixture a in the multi-component heat exchanger

32

2.10 Calculation j Cooling requirement for condensation H ₂ O in the multicomponent heat exchanger

2.11 Calculation of k cold from step-by-step 1. Heating of the gas mixture b

2.12 Calculation I cold from 2. Heating of the gas mixture b

2.13 Calculation of m cold from heating the liquid CO ₂

List of reference symbols

1 .. Gas mixtures and substances

10 Raw exhaust gas with the components N ₂ , 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 the CO 2} 11c gas mixture a, recooled

11 d gas mixture a, cooled to condensation temperature of CO ₂ 11 e 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 residues 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 expanded 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 cooled in the initial state 17b gas mixture c

18 gas mixture d

19 Gas mixture pressurized

19a gas mixture e expanded at low temperature 19b gas mixture e expanded and heated

2 .. components of the system

20 emission control level

21 cooling tower

21a exhaust gas cooler a b exhaust gas cooler bc exhaust gas cooler cd cooling water pump ae cooling water pump bf cooling water pump cg cooling water circulation exhaust gas turbo compressor a exhaust turbo-compressor stage 1 b exhaust turbocompressor 2nd stage multi-component heat exchanger a self-cleaning heat exchange component b engine flaps heat-emitting side of the self-cleaning heat exchange component c motor flaps heat-absorbing side of the self-cleaning heat exchange component d check valves heat-emitting side of the self-cleaning heat exchanger component e non-return valves heat-absorbing side of the self-cleaning heat exchanger component f heat exchanger component a for gas mixture bg heat exchanger component b for highly compressed CO ₂ a CO ₂ condenser b CO ₂ condenser heat-emitting side c CO ₂ condenser heat-absorbing side d CO ₂ separator e CO ₂ high pressure pump f high pressure ag Connection point bh heat exchanger component of the heat-absorbing side of the CO ₂ condenser a adsorber a for CO ₂ b adsorber b f For CO ₂ c changeover valve for adsorber ad changeover valve for adsorber ae changeover valve for adsorber bf changeover valve for adsorber ba fan b control valve a 26c non-return valve 27 refrigeration circuit

27a coolant / gas heat exchanger

27b Coolant / gas heat exchanger heat-emitting side

27c coolant / gas heat exchanger heat-absorbing side

27d control valve b

27e secondary refrigerant pump

28a gas turbine a

28b gas turbine b

28c multistage gas turbine

29 Connection for start-up operation with external N ₂

29a Changeover valve for start-up Z control mode

29b Switchover valve for start-up Z control mode

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

31 a Dissipated heat, exhaust gas cooler a 31 b Dissipated heat, exhaust gas cooler b 31 c Dissipated heat, exhaust gas cooler c 32a Work of the gas turbine a

32b work of the gas turbine b

32c work of the multistage 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 41 a CO ₂ pipe a

41 b CO ₂ pipe b

41 c 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 pipe f

42g nitrogen tube g

42h nitrogen tube h

42 i nitrogen tube i

42j nitrogen tube j

42k nitrogen tube k

42 l nitrogen tube I.

42m nitrogen pipe w

43a cooling water pipe a

43b cooling water pipe b

43c cooling water pipe c

43d cooling water pipe d

43e cooling water pipe e

43f cooling water pipe f

44a drainage pipe a

44b drainage pipe b

44c drainage pipe c

45a cold pipe a

45b cold pipe b

45c cold pipe c

45d cold pipe d

Claims

A method for turbo exhaust gas CO2 separation from exhaust gas that has been cleaned of particles, with liquid CO2 removal at condensation pressure, comprising the steps: A. In method step A, the exhaust gas (10a) is cooled and that contained in the exhaust gas Water vapor (14a) is condensed and separated, with the exception of a residual proportion of water vapor corresponding to the saturation pressure of the water vapor in the gas mixture; B. The remaining gas mixture a (11a) is compressed in process step B to the pressure required for the condensation of CO2 and cooled back; C. In process step C, the gas mixture a (11c) is cooled in the multi-component heat exchanger (23) to the condensation temperature of CO2 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 CO2 (13) is condensed in the CO2 condenser (24a) and separated in liquid form from the exhaust gas, the remaining gas mixture b (12a) still containing a residual proportion of CO2 corresponding to the saturation pressure of the CO2 in the gas mixture; K. In method step K, the gas mixture b (12a) is cleaned of the remaining CO2 by adsorption; L. In process step L, the gas mixture b (12b) is expanded while performing work so that the coldness of the expanded gas mixture b (12c) is sufficient for the CO2 evaporation enthalpy to be removed in the CO2 condenser (24a,); M. In process step M, the expansion cold of gas mixture b is used to condense the CO2 component in gas mixture a (11 d) in CO2 condenser (24a,) N. In process step N, the coldness of 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 0, the heated gas mixture c (12c) is expanded to atmospheric pressure while doing work in the gas turbine b (28b); P. In process step P, the cold expanded gas mixture b (12g) is heated in the self-cleaning heat exchanger component (23a), and the heated gas mixture b (12f) absorbs the deposited H2O from process step C and, after exiting the self-cleaning heat exchanger component (23a) ) discharged into the atmosphere. Claim 2 The method for turbo exhaust gas CO2 separation from exhaust gas according to Claim 1, characterized in that the following process steps are additionally provided: F. In process step F, the CO2 (13) separated in process step D is removed and fed into the CO2 high-pressure pump (24e ), then the liquid CO2 (13) is compressed with the CO2 high-pressure pump (24e) to the pressure required for underground storage andG. In process step G, the highly compressed CO2 (13a) is heated in heat exchanger component b (23g). Claim 3 device for turbo exhaust gas CO2 separation of liquid CO2 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 for CO2 separation the components: • an exhaust gas cooler a (21 a ); • a single-stage or multi-stage exhaust gas compressor (21, 22, 22a); • an exhaust gas cooler b (21 b); • a self-cleaning heat exchanger unit (23a) connected via the motor flaps on the heat-emitting side (23b); • a CO2 condenser (24a) connected to the heat-emitting side (24b) and • a CO2 separator (24d); wherein the individual components are fluidly connected to one another in the order mentioned by pipelines; B. In the direction of flow of the CO2 separated off in the CO2 separator (24d), a connection point a (24f) for the downstream use of the separated CO2; C. In the direction of flow of the gas mixture b (12a) separated in the CO2 separator (24d), the components: • a CO2 adsorber (25a, 25b); • a single-stage or multi-stage expansion turbine (28a, 28c); • the CO2 condenser (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 on the heat-absorbing side (23c) and • an outlet opening for the moist gas mixture b (12f) into the atmosphere; the individual components being fluidly connected to one another in the order named by pipelines. Claim 4 device for turbo exhaust gas CO2 separation according to claim 3 which additionally has the following components: D. In the direction of flow of the CO2 separated from the CO2 separator, the components: • A CO2 floch pressure pump (24e) • a heat exchanger component (23g) for highly compressed CO2 (13a) • A connection point b (24b) for forwarding the highly compressed CO2 to a downstream CO2 storage or CO2 utilization; wherein the individual components are fluidly connected to one another in the order mentioned by pipelines. Claim 5 device for the condensation of CO2 in gas mixtures with a pressure between 6 and 15 bar, which has the following components: A. in the direction of flow of the gas mixture (19) to be fed to the device, the components:

1. a CO ₂ condenser (24a) with the heat-emitting side (24b) and

2. a CO ₂ separator (24d); wherein the individual components are fluidly connected to one another in the order mentioned by pipelines;

B. In the direction of flow of the pressurized gas mixture e (19) used for cooling, the components

3. a single-stage or multi-stage expansion turbine (28a, 28c)

4. a CO ₂ condenser (24a) with the heat-absorbing side (24c); wherein the individual components are fluidly connected to one another in the order mentioned by pipelines.

Claim 6

Device for the condensation of CO ₂ in gas mixtures according to claim 5, wherein a multi-stage expansion turbine (23C) is provided, in which the heat-absorbing side of the CO ₂ condenser (24c) is divided into several fluidically separated heat exchanger components (24h) and each of these Heat exchanger components (24h) are fluidly connected to each stage of the multi-stage expansion turbine (23c).

Claim 7

Apparatus for the condensation of CO ₂ in gas mixtures according to claim 5, which additionally has the following components:

C. In the direction of flow of the pressurized one used for cooling

Gas mixture e (19) between the expansion turbine a (28a) and the CO ₂ condenser (24a) the components:

5. a control valve (26b) for conditioning the temperature of the gas mixture e (19);

6. a regulated compressor (26a) for conditioning the flow rate of the gas mixture e (19); wherein the individual components are fluidly connected to one another in the order mentioned by pipelines.

Claim 8

D. In the direction of flow of the pressurized one used for cooling

Gas mixture e (19) between the expansion turbine a (28a) and the CO ₂ condenser (24a) of the refrigeration circuit (27) with the components:

7. a coolant / gas heat exchanger (27a) with the heat-emitting side (27c);

8. a control valve (27d) for conditioning the temperature of the refrigerant (15);

9. a regulated pump (27e) for conditioning the flow rate of the refrigerant (15); wherein the individual components of the refrigeration circuit are fluidly connected to one another in the order mentioned by pipelines.