Field of Invention

The subject of the invention is a method and a system for producing electric power and a synthesis gas from a coal fuel in emission-free coal-nuclear synergy technology and its use to the production of synthetic liquid fuels, in particular from a coal fuel gasified in an oxygen without emission of carbon dioxide to the atmosphere and then liquefied in the preferred use for producing synthetic liquid fuels.

The presented innovation refers in particular to a new process and a system for generating electric energy and synthesis gas from coal fuel without emissions of carbon dioxide, as well as nitrogen compounds NO _x into the atmosphere, wherein this innovation is implemented in the emission-free coal-nuclear synergy technology (BSWJ) according to the preamble of the independent claims.

The invention also includes the use of the new method and the system for generating electric energy and synthesis gas in the production process of synthetic liquid fuels from a coal fuel and an technological installation for its realization. State of the Art

A process for producing electric energy and synthetic liquid fuels from a coal fuel by means of liquefaction of synthesis gas is widely known. There is well-known coal-fired power plant adapted for the combustion of a coal fuel in oxygen, which was implemented and operated in 2008 in Schwarze Pumpe by the Vattenfall concern of Sweden. Currently Swedish Vattenfall and British Oxycoal UK concerns are working together to improve the technology of combustion or gasification of coal fuel in oxygen. In known solutions, the oxygen fed to the combustion chamber or to a coal fuel flow gasifier is obtained in the process of air separation into an oxygen O2 and a nitrogen N2, for example using an ionic membrane. As a result of combustion or gasification of a coal in pure oxygen a much higher efficiency of coal- fired power plant is obtained, as well as much smaller amount of exhaust gas is produced that amount is even three times lower in relation to the amount of exhaust gas produced during combustion of a coal fuel in the air, and additionally the amount of exhausted harmful nitrogen oxides NO _x is practically reduced to zero. However, the obtained amount of carbon dioxide CO2 is not reduced, which according to the zero-emission concept is, for example, captured from exhaust gas using known methods for storage in underground chambers, for example in inactive mines.

Another methods for obtaining pure oxygen O2 are also known, for example by means of an electrochemical reaction, i.e. a high-temperature water electrolysis reaction (2¾0 2¾ + O2) (water-splitting). For example, the known and commercially available SOEC type solid oxide electrolysers are used for high-temperature water-splitting in electrochemical electrolysis into a hydrogen and an oxygen. In this type of electrolysers the electrochemical reaction is operated at high-temperature, usually approximately 1000°C, using a solid porous electrolyte mostly based on a bismuth oxide and zirconium oxide, for decomposing water into a hydrogen and an oxygen. Using electric power obtained from nuclear reactors to feed the high-temperature electrolysis process is also known. There is also known high-temperature helium-cooled nuclear reactor of fourth generation VHTR-PM type, for example, 200 ME _e power which is currently tested in China.

Methods and installations for producing synthesis gas in the form of a mixture (CO + ¾) - carbon monoxide (CO) and a hydrogen (¾), which can be used as a substrate for the production of light liquid hydrocarbons or synthetic liquid hydrocarbon fuels, are known in the art.

According to known solutions, synthesis gas is usually produced by coal fuel steam reforming process, usually coal or lignite (brown coal) or other substances, including carbon- containing organic wastes, in coal gasification installation, which comprises the following technological equipment: a coal drying unit comprising a heat exchanger and a system for removal moisture from a coal, an unit for grinding and pulverizing a coal into particles suitable for gasification process, a gasification unit, preferably a dust flow generator supplied with appropriately powdered or ground coal, preferably a coal dust, and in which said coal is gasified in the presence of an oxygen O2, that is fed to the gasification unit from a cryogenic unit for separation of an air into an oxygen (O2) and a nitrogen (N2), and a steam. As a result of gasification and pyrolysis of pulverized coal in the gasification unit a synthesis gas is produced comprising carbon monoxide (CO) and a hydrogen (¾) as well as admixtures of other gaseous materials or substances and a water and a slag. In further step of the process, the obtained synthesis gas is subjected to a treatment involving cooling to about 160 ^° C, removal of water condensate and subsequent purification from admixtures using several different purification steps, including purification in the activated carbon bed to remove undesired mercury-containing impurities and other solid contaminants, e.g. heavy metals, purification in the RectisoF process to remove admixtures of hydrogen sulphide (FhS) and carbon dioxide (CO2) and other purge gas there from, which are then further processed according to known methods.

For example, the raw (synthesis) gas stream produced in the steam reforming process, after purification according to the known solutions described above, is directed to a Fischer-Tropsch reactor in which a catalytic reaction is carried out, the product of which is a hydrocarbon mixture, wherein the hydrocarbon mixture obtained in this process (I-cycle) is purified from the synthesis gas residue that is directed (i.e. returned to the process) to the input of the Fischer-Tropsch reactor, or to the attached subsequent Fischer-Tropsch reactor of the Il-nd cycle and after mixing with raw synthesis gas the resulted mixture is transformed there again into a mixture of liquid hydrocarbons, as in the I-st cycle. After separation of the cooled and purified mixture of hydrocarbons in the separation unit into the first light hydrocarbon product consisting of light fraction hydrocarbons and distillates of middle fraction hydrocarbons, and the second heavy hydrocarbon product consisting of heavy fraction hydrocarbons, the latter product is converted in a hydrocracking process into lighter fractions of hydrocarbons and liquid hydrocarbon fuel which are mixed in appropriate tanks with the said first light hydrocarbon product, wherein the product obtained by the Fischer- Tropsch process in the form of light hydrocarbons is separated in a distillation column into two products, i.e. petroleum fuel (methanol) and diesel fuel.

One of many known processes for converting coal fuel into liquid hydrocarbon fuels is the known Fischer-Tropsch process in which synthesis gas is converted into many different forms of liquid products. For example, the known in the art process (UPW) 1-00 for coal fuel liquefaction is disclosed, for example, in the preamble part of US2008/0103220 describing known state of the art for coal fuel liquefaction.

For example, the conventional (UPW) 1-00 process for coal fuel liquefaction (CTL) known from the prior art, illustrated by mass and thermal energy streams, is schematically shown in fig. 1, by reference. The (UPW) 1-00 process for coal fuel liquefaction consists of many sub-processes included within the (UPW) 1-00 process. For example, the conventional (UPW) 1-00 process for coal fuel liquefaction according to prior art can include sub-process I- 10 for steam reforming coal fuel gasification, sub-process 1-20 for recovering gas and thermal energy, sub-process 7-30 for purifying gas, Fischer-Tropsch sub-process 1-60 and sub-process 1-30 for recovering thermal energy and producing electric energy. Each of these sub-processes illustrated in fig. 1 is separated by dashed lines.

A sub-process I- 10 for steam reforming coal fuel gasification of the (UPW) 1-00 process for coal fuel liquefaction is operated in a technological installation that includes: a dryer 1-12, a dust mill 1-14, a coal fuel gasification unit, preferably a coal fuel flow gasifier 7- 16 and an air separator 1-18. The coal fuel 1-11 used in the sub-process for coal fuel gasification is directed to one or more dryers 1-12 in order to reduce the moisture in the coal fuel 1-11. A moisture removed from the coal fuel 1-11 can be removed from the dryer 1-12. The dryer 1-12 may comprise a heat exchanger or other conventional typical technological equipment operating drying processes appropriate to the process (UPW) 1-00 for coal fuel liquefaction. The dry coal fuel 1-13 is crushed and ground, or otherwise reduced to the right sizes for gasification of a coal fuel. The crushed and ground coal fuel 1-15 enters into and feeds the coal fuel flow gasifier 1-16, where the coal fuel is gasified in a presence of an oxygen and a steam. The air separator 1-18, such as, for example, a cryogenic air separator, is supplied with air, which air is splitted i.e. is separated into a nitrogen N2 and an oxygen O2. The nitrogen is released into the environment in the nitrogen mass stream I-18b, while the oxygen mass stream I-18a is fed to and supplies the coal fuel flow gasifier 1-16.

The mass stream 1-15 of crushed and ground coal fuel is gasified in the coal fuel flow gasifier 1-16 in the oxygen mass stream l-18a in the presence of the steam mass stream 0 fed to and supplying the coal fuel flow gasifier 1-16. A water from a water reservoir (ZW), forming a water mass stream 2, can also be fed and supply the coal fuel flow gasifier to absorb thermal energy produced in the gasification process, while creating a medium pressure steam mass stream 4 that may flow out of the coal fuel flow gasifier 1-16 and can be used anywhere in the (UPW) 1-00 process for coal fuel liquefaction (CTL). By means of combustion, pyrolysis and gasification of crushed and ground coal fuel 1-15, supplying the coal fuel flow gasifier 1-16, a raw synthesis gas I-16a and a slag I- 16b are produced in this gasifier. The raw synthesis gas mass stream I-16a flows out of the coal fuel flow gasifier 1-16 and from the coal fuel gasification sub-process 1-10 and flows into the sub-process 1-20 for recovering gas and thermal energy. The slag I-16b is removed from the coal fuel flow gasifier and is available for any conventional recycling method. The raw synthesis gas mass stream I-16a from the coal fuel flow gasifier contains carbon monoxide (CO), hydrogen (¾) and another gas products. The hot raw synthesis gas mass stream I-16a supplies the heat exchanger in the sub-process 1-20 for gas and thermal energy recovering. The heat exchanger cools the hot raw synthesis gas mass stream and produces a raw synthesis gas cold stream that is discharged from the heat exchanger. The raw synthesis gas cold stream is then directed to the sub-process 1-30 for gas purification.

The hot raw synthesis gas mass stream 1-16a flowing into the heat exchanger can be mixed with the cooled gas mass stream from the sub-process 1-30 for gas purification that is compressed by one or more compressors. The water mass stream 2 which flows out of the water tank (ZW) can also be directed to the heat exchanger. The water mass stream 2 absorbs thermal energy from the heat exchanger producing the high-pressure steam mass stream 6 and the medium pressure steam mass stream 4. The high-pressure steam mass stream 6 generated in the heat exchanger is divided into individual sub-processes. The high-pressure steam mass stream 6 may feed, among others, the reactor 1-30 for changing acidity in the sub-process for gas purification. The medium pressure steam stream 4 produced in the heat exchanger can be recovered and used anywhere in the (UPW) 1-00 process. The sub-process 1-30 for gas purification is used to remove impurities and other unwanted products from the cooled raw synthesis gas, produced in the sub-process 1-10 for coal fuel gasification, and introduced into the sub-process 1-30 for gas purification. The sub-process 1-30 for gas purification installation includes a filter (cyclone), an aqueous gas scrubber, a waste water treatment plant, an acidity changing reactor, a heat exchanger, a condenser and an activated carbon bed. The sub-process 1-30 for gas purification contains also technological equipment for removing hydrogen sulphide (H2S) and carbon dioxide (CO2) from raw synthesis gas.

The cooled raw synthesis gas mass stream is directed to a filter (cyclone) for removing ash and other impurities from the raw synthesis gas mass stream. The synthesis gas mass stream is then directed to the synthesis gas water scrubber. The water scrubber removes (rinses) impurities from the cooled synthesis gas mass stream. The synthesis gas mass stream is then divided into a first synthesis gas stream which is directed to the acidity changing reactor and to a second synthesis gas mass stream, which bypasses the acidity changing reactor and is mixed with the synthesis gas mass stream flowing out of the acidity changing reactor. The first mass stream of the rinsed synthesis gas entering the acidity changing reactor is mixed with the high-pressure steam mass stream 6 flowing into the reactor to achieve the desired ratio of a hydrogen ¾ to carbon monoxide CO. Change in the relative amounts of a hydrogen ¾ to carbon monoxide CO in the modified synthesis gas flowing out of the acidity changing reactor can be controlled by mixing the two synthesis gas mass streams to receive as a product a synthesis gas mass stream with the desired ratio of hydrogen ¾ to carbon monoxide CO for the Fischer-Tropsch sub-process 1-60. The mass stream of waste water is directed to the treatment plant using conventional methods of waste water treatment. The synthesis gas mass stream is directed to the heat exchanger, that cools the synthesis gas mass stream, to which exchanger the water mass stream 2 from the water reservoir (ZW) is fed, and in which exchanger a medium pressure steam 4 is generated, the mass stream of which can be used in another part of the (UPW) 1-00 process for coal fuel liquefaction.

The cooled in the heat exchanger synthesis gas mass stream is directed from the heat exchanger to the condenser, where water from the cooled synthesis gas mass stream condenses and the condensed mass stream of the condensed water is removed from the cooled synthesis gas. The water mass stream may be directed to the synthesis gas scrubber in the sub process 1-30 for gas purification. The synthesis gas mass stream flowing out of the condenser is directed to the activated carbon bed. The activated carbon bed removes mercury from the synthesis gas mass stream. A part of the synthesis gas mass stream free of mercury after passing through the activated carbon bed can be recycled to the compressor in the sub-process for gas and thermal energy recovering and then can be mixed with the synthesis gas mass stream I-16a, to form a common mass stream supplying the synthesis gas heat exchanger. The remaining or residual part of the synthesis gas mass stream is fed to the Rectisol process in which hydrogen sulphide (HhS) and carbon dioxide (CO2) are removed from the synthesis gas mass stream. In the Rectisol process, hydrogen sulphide and carbon dioxide are removed from the synthesis gas mass stream and the following gas mass streams are produced: a gas containing hydrogen sulphide and carbon dioxide, a gas containing carbon dioxide, a pure gas, a pure synthesis gas i.e. syngas.

The first gas mass stream mentioned above can supply the Claus process in which sulphur is removed from gaseous hydrogen sulphide from the gas mass stream. The final gas mass stream downstream the Claus process feeds the SCOT process, which continues to operate until the gas is completely purified in this process.

The said second gas mass stream containing carbon dioxide is compressed in the first compressor and then mixed with glycol triethylene (TEG) in a dehydration process, in which water is removed from the gas mass stream and can be used anywhere in the sub-process 1-10. The gaseous carbon dioxide from the (TEG) process is compressed in the compressor 6, and then cooled down to the liquid state. The liquid carbon dioxide is pumped into tanks or it can be used in another processes.

The pure gas mass stream obtained in the Rectisol process is released into the environment.

The Rectisol, Claus, SCOT processes and the dehydration process (TEG) are commonly known and used to remove sulphur, carbon dioxide and other pollutants in the (UPW) 1-00 process for coal fuel liquefaction.

The syngas mass stream 1-47 downstream the purification sub-process is delivered to the Fischer-Tropsch sub-process 1-60 where the syngas mass stream 1-47 is converted into a liquid synthetic fuel. The technological installation of the Fischer-Tropsch sub-process consists of a first Fischer-Tropsch reactor 1-62, a first heat exchanger 1-64, a first separation unit 1-66, a compressor 1-68, a second Fischer-Tropsch reactor 1-72, a second heat exchanger 1-74, a second separation unit 1-76, a hydrocracker 1-70, a hydrogen separation membrane I- 78, a second compressor 1-80, a tank 1-82 and a distillation column 1-84 .

The syngas mass stream 1-47 from the sub-process 7-30 for gas purification contains hydrogen (¾) and carbon monoxide (CO).

In the 1-60 Fischer-Tropsch sub-process the syngas mass stream 1-47 feeds the first Fischer-Tropsch reactor 1-62, where hydrogen and carbon monoxide in the syngas mass stream 1-47 are converted into liquid fuel in the catalytic reaction represented by equation (1):

Where n is a natural number and may range from 1 to about 42, although it may be greater than 42. For example for light hydrocarbons n may be in the range from 1 to about 7, for intermediate hydrocarbons n may be in the range from about 8 to about 13, and for heavy hydrocarbons n can take values above 14.

The first hydrocarbons mass stream 1-63 flowing out from the first Fischer Tropsch reactor 1-62 contains both liquid fuel and a gas from the first Fischer Tropsch reactor 1-62, which are cooled in the first heat exchanger 1-64, to which a water mass stream 2 from the water reservoir (ZW) is supplied and absorbs heat from the first hydrocarbons mass stream I- 63 while producing a medium pressure steam mass stream 4, which is purified in another process. The cooled first hydrocarbon mass stream 1-63 feeds the first separation unit 1-66, where different components from the first hydrocarbons mass stream 1-63 are separated. The syngas mass stream 1-67 generated from the gas mass stream 1-63 as a result of separation in the first separation unit 1-66 and purified feeds the second Fischer-Tropsch reactor 1-72. The liquid fuel mass stream resulting from the first hydrocarbons mass stream 1-63 is separated in the first separation unit 1-66 into two hydrocarbon mass streams: the first light hydrocarbons mass stream I-66a containing intermediate distillates and light hydrocarbons and the first heavy hydrocarbons mass stream I-66b containing heavy hydrocarbons. The first separation unit 1-66 also removes water 8 from the first hydrocarbons mass stream 1-63 and purifies the water mass stream 8 from other products. The syngas mass stream 1-67 from the first separation unit 1-66 is compressed in a compressor 1-68 and is directed to and feeds the second Fischer-Tropsch reactor 1-72, where the syngas mass stream 1-67 is converted in the catalytic reaction into liquid fuel, according to reaction equation (1) while forming a second stream 1-73 of hydrocarbons.

The second hydrocarbons mass stream 1-73 from the second Fischer-Tropsch reactor 1-72 is cooled in the second heat exchanger 1-74 and then directed to the second separation unit 1-76. The second heat exchanger 1-74 is supplied with water mass stream 2 from the tank (ZW), which absorbs heat from the second hydrocarbons mass stream 1-73 while producing medium pressure steam mass stream 4, which is purified for use in another sub-processes of the (UPW) 1-00 process for coal fuel liquefaction.

The second separation unit 1-76 separates i.e. splits the second hydrocarbons mass stream 1-73 into its various components. The water 8 separated from the second hydrocarbons mass stream 1-73 is purified in the second separation unit 1-76 and can be used anywhere. The liquid fuel from the second hydrocarbons mass stream 1-73 is separated into two mass streams: the first stream I-76a from the second light hydrocarbons mass stream 1-73 comprising intermediate distillates and light hydrocarbons, and the second stream I-76b from the second heavy hydrocarbons mass stream containing heavy hydrocarbons. The final gases 1-77 separated from the second hydrocarbons mass stream 1-73 in the second separation unit 1-76 are directed to the hydrogen separation membrane 1-78, from which the hydrogen (¾) mass stream 1-79 obtained from the final gases is directed to the compressor 1-80.

The heavy hydrocarbons produced in the Fischer-Tropsch sub-process 1-60 are converted in the hydrocracker 1-70 to light hydrocarbons or liquid fuels. The first heavy hydrocarbons mass stream I-69b and the second heavy hydrocarbons mass stream I-76b produced by the Fischer-Tropsch reactors are mixed with each other forming the hydrocarbons mass stream 1-69 feeding the hydrocracker 1-70.

The heavy hydrocarbons mass stream 1-85 from the distillation column 1-84 also feeds the hydrocracker 1-70. Hydrogen 1-79 separated from the final gases 1-77 by the membrane 1-78 for hydrogen separation is compressed by means of the compressor 1-80 before feeding the hydrocracker 1-70 to facilitate the hydrocracking process of light hydrocarbons or liquid fuels to create hydrocarbon mass stream 1-71 flowing out from the hydrocracker 1-70.

Said hydrocarbons mass stream 1-71 is combined with the second light hydrocarbons mass stream I-76a and with the first light hydrocarbons mass stream I-66a and then these streams are mixed in a tank 1-82 to form light hydrocarbons mass stream 1-83. The light hydrocarbons mass stream 1-83 feeds the distillation column 1-84. Inside the distillation column 1-84, the products of light hydrocarbons 1-83 from the Fischer-Tropsch sub-process 1- 60 are distilled into heavy gasoline 1-86 and diesel oils 1-87. The heavy hydrocarbons mass stream 1-85 produced in the distillation column 1-84 is removed from the distillation column 1-84 and directed to the hydrocracker 1-70. The pure gases 1-88 from the distillation column I- 84 can be combined with the final gas 1-77 and then feed the hydrogen separation membrane 1-78 to separate hydrogen from the pure gases 1-88.

The (UPW) 1-00 process for coal fuel liquefaction according to the prior art, or, for example, according to US2008/0103220 patent in its initial part relating to the known state of the art for coal fuel liquefaction, may include the sub-process 1-90 for heat recovery and electric energy production. The thermal energy recovery and electric energy production in the sub-process 1-90 results from the conversion of a heat from the (UPW) 1-00 process into electric energy. The recovered mass streams of high-pressure steam 6 and medium pressure steam 4, obtained in the (UPW) 1-00 process for coal fuel liquefaction supply with the recovered steam the steam generator, to which the water mass stream 2 from the water tank (ZW) and the exhaust gas mass stream are also supplied.

The final gas 1-91 obtained from the hydrogen separation membrane 1-78 mixed with an air 1-19 is burned in a gas turbine connected to an electric generator. The exhaust gas flowing out from the gas turbine is directed to the heat recovery generator from a steam and heats up the water mass stream 2 from the water tank (ZW) and the recovered high and medium pressure steam mass streams 6 and 4 supplying the said heat recovery generator. The very high-temperature steam produced in the said heat recovery generator supplies the condensing turbine that produces electric energy from the expansion and cooling of the very high-temperature steam. A water produced in the condensing turbine is directed to the pump and is pumped in the water mass stream 2 to the water tank (ZW). The exhaust gas is cooled in the heat recovery generator from a steam and then directed to a chimney. The gases flowing out of the chimney can be further purified or released into the natural environment.

It should be noted that as a result of the above-described process, a large amount of carbon dioxide is produced, which is either released into the environment or directed to a storage (see Table I). Currently, the technology for converting a coal fuel, especially hard coal, into a synthesis gas in which there would be no emission of large amount of carbon dioxide or such emission would be kept at a minimum level acceptable for environmental protection, is not known.

Currently, there is virtually no technology that would allow the generation of electric and thermal power from fuel coal, in particular hard coal, in a way free from the emission of large amount of carbon dioxide, which to a large extent is released to the atmosphere, because possibilities of its use in industry are rather poor, whereas its processing is hardly profitable economically, while its storage is technically complex and carries environmental risks as well as is very expensive. No technology is also known by which synthesis gas can be cost- effective produced for supplying the process of production synthetic liquid fuel from a coal fuel without emitting large amounts of carbon dioxide, which emission is unacceptable from the point of view of environmental protection. Therefore, there is a particular need to develop a new technology for producing electric power from a coal, preferably hard coal, as well as for producing synthesis gas, which technology can provide a significant reduction in the emission, and preferably zero-emission, of carbon dioxide while maintaining the cost- effectiveness of the process from point of view of the production costs of such energy as well as synthesis gas.

The solution of the problems described above has been proposed in accordance with the invention by means of a method and a system for producing electric power and synthesis gas from a coal fuel in an zero-emission coal-nuclear synergy technology and their preferred applications.

The object of the Invention There is therefore a great need to develop an improved technological process (a method) and technological installation (a system) for converting a coal fuel, especially hard coal and a coal fuel containing materials for the production of electric power and a heat without emission of carbon dioxide and other harmful gaseous substances, such as nitrogen compounds NO _x .

There is also a great need to develop an improved technological process (a method) and technological installation (a system) for converting a coal fuel into synthesis gas and then into synthetic hydrocarbon liquid fuels, which would also ensure high performance and efficiency of the process and reduced fuel costs compared to known methods, comparable to the costs of producing such a fuel from raw oil, with simultaneously reduced amount of harmful substances produced as by-products, such as compounds containing sulphur and nitrogen oxides, in particular a substantially reduced carbon dioxide emission.

Summary of the Invention

According to the invention, a method and a system for the production of electric power and a synthesis gas from a coal fuel in an emission-free coal-nuclear synergy technology has been developed, especially zero-emission technology for producing synthesis gas, in particular from coal fuel, in particular hard coal, preferably without carbon dioxide emission to an atmosphere, wherein in a preferred embodiments of use of the invention, in accordance with the embodiment of the invention, the method and the system according to the invention can be applied in a process by which the synthesis gas can be further processed into a synthetic hydrocarbon liquid fuel.

According to the invention, in order to solve the above-discussed, known from the prior art, problems associated to the production of synthesis gas and electric power from coal fuel, in particular hard coal and carbonaceous products, a method is proposed comprising a plurality of component technological sub-processes for converting coal fuel into synthesis gas in a cost-effective way, while simultaneously protecting the environment, in which method carbon dioxide emission has been almost completely eliminated. In a preferred application of the invention, the synthesis gas produced according to the invention can be further converted into hydrocarbon liquid fuel, in particular methanol, synthetic gasoline and synthetic diesel fuel using a modernized technological installation in the form of a system containing in particular a modified technological installation for coal fuel gasification sub-process with no steam reforming process and without the production of carbon dioxide and, in the use of the invention, a Fischer-Tropsch installation, as well as a modernized technological installation for a high-temperature electrolysis sub-process comprising a set of at least one high- temperature helium-cooled IV-Generation nuclear reactor for supplying a high-temperature electrolysis sub-process, in particular a high-temperature electrolyser.

The invention relates in particular to an improved emission- free method for the production of electric energy and synthesis gas and a system for its implementation using emission-free coal-nuclear synergy (BSWJ), which method provides an environment friendly technology allowing emission-free generation of electric power from coal fuel in a coal-fired power plant and synthesis gas, with practically total elimination of carbon dioxide CO ₂ and nitrogen oxides NO _x emissions to the atmosphere.

The method according to the invention allows practically emission-free electric energy generation from coal fuel, in particular hard coal, in a modified installation for coal fuel gasification in oxygen, or alternatively in a combustion chamber of a modified coal-fired power plant.

According to the invention it is provided the method (UPW) II-OO for producing electric power and synthesis gas from a coal fuel by mean of emission-free coal-nuclear synergy technology, which coal fuel is gasified in an oxygen, wherein the method containing the coal fuel gasification sub-process in a gasifier in an oxygen, in which sub-process a gaseous product is produced, in particular a gas in the form of a mass stream of the gaseous product, as well as a slag and a thermal energy are produced, said thermal energy being used for generating a steam, by means of at least one heat exchanger, and an electric energy, by means of at least one steam turbine which is coupled with a current generator, a thermal energy recovery sub-process, in which high pressure steam is generated, using the mass stream of the gas produced in at least one coal fuel gasifier by means of at least one heat exchanger, and in which an electric energy is generated, using at least one power generator, a sub-process of purification of the gas generated in the coal fuel gasification sub-process in at least one gasifier, a high-temperature electrolysis sub-process, in which an oxygen for supplying the coal fuel gasification sub-process is produced in the electrochemical electrolysis reaction, said method being characterized by further comprising a separate sub process for producing synthesis gas, which is a mixture of two gaseous components: a carbon monoxide (CO) and a hydrogen (¾) and by that in said method (UPW) II-OO for producing electric energy and synthesis gas from a coal fuel, both components of the synthesis gas, i.e. a carbon monoxide (CO) and a hydrogen (¾) are produced separately, by means of separate sub-processes both included in said method.

Namely, a carbon monoxide (CO) is produced in the cool fuel gasification sub-process in oxygen, while a hydrogen (¾) is produced in the high-temperature electrolysis sub-process, and then the above mentioned two components of the synthesis gas, after attaining the appropriate thermodynamic parameters, such as in particular: a temperature and a pressure, in subsequent sub-processes of the said method (UPW) 11-00) for producing electric energy and synthesis gas from a coal fuel, particularly at least in the thermal energy recovery sub-process, are directed separately, respectively, in the form of the pure carbon monoxide mass stream, after its previous purification in the gas purification sub-process, and in the form of the hydrogen mass stream, to the subsequent synthesis gas production sub-process, comprising the installation of a mixing converter, in which sub-process both the above components of the synthesis gas, that is the hydrogen mass stream and the pure carbon monoxide mass stream are mixed with each other in a suitable mole ratio in the said mixing converter. In addition said sub-processes, i.e. the coal fuel gasification sub-process and the high-temperature electrolysis sub-process are carried out in emission-free technology, preferably without emission of any carbon dioxide (CO2) to the environment.

In the embodiment of the invention the method is further characteristic by that the coal fuel, preferably ground and dried, is gasified in the coal fuel gasification sub-process in an oxygen (O2), which is delivered in the form of the oxygen mass stream into a modified installation of the coal fuel gasification sub-process, preferably to a coal fuel gasifier, in particular a flow gasifier, via a check valve controlling a value of the oxygen mass stream in such a way, that the coal fuel fed to the gasifier is gasified approximately only while producing a gaseous product in the form of a carbon monoxide (CO) mass stream (II- 16a), wherein next in the gas purification sub-process the mass stream of polluted carbon monoxide exiting the gasifier is subjected to purification from pollutants, particularly such as gas admixtures, especially hydrogen sulphide and carbon dioxide, solid substances, especially a mercury, and a water, produced in the process of coal fuel gasification in an oxygen.

Whereas, in the embodiment of the invention, the second synthesis gas component - that is the hydrogen (¾) is produced in a high-temperature electrolysis sub-process, preferably using one or more high-temperature electrolysers, in which the electrochemical electrolysis reaction of the high-temperature steam supplied to this sub-process in the form of a high-temperature steam mass stream produced in a heat exchanger which is in fluid communication to the installation of a high-temperature helium-cooled nuclear reactor, wherein the said high-temperature steam mass stream is decomposed into a hydrogen (¾) and an oxygen (O2) and which said electrolysis sub-process is supplied with electric energy, at least produced using the nuclear reactor, preferably the high-temperature helium-cooled nuclear reactor of fourth generation, and further wherein the oxygen (O2) produced at the same time in the high-temperature electrolysis sub-process is used, at least partly, to supply the coal fuel gasification sub-process (II- 10) and is fed to the flow gasifier in a controlled manner in the form of the oxygen mass stream via a control check valve, co-operating with the controlling system for controlling the oxygen mass stream current value, said system containing a carbon dioxide sensor.

In the embodiment of the invention the method is further characteristic by that, the oxygen mass stream fed to the gasifier is throttled by means of the check valve operating in a negative feedback conjugation system in cooperation with the carbon dioxide sensor emitting feedback control signal, preferably electric signal, informing about detection of the presence of carbon dioxide (CO2) in the gas, which is the gaseous product of the coal fuel gasification in the gasifier, in an amount exceeding the established upper limit of the percentage of CO2 mass stream in the total mass stream of the gaseous product of the coal fuel gasification, preferably about 0.1% value of the total mass stream of the gaseous product of the coal fuel gasification, and transmitting the said signal to the feedback executive converter, preferably electric, being in the signal transmitting communication with said check valve which converter generates an actuating control signal transmitted to the check valve, wherein said check valve being connected to the oxygen supplying conduit to the gasifier, which said check valve controls the current value of the oxygen mass stream supplying the coal fuel gasifier with the oxygen in such a way that the whole coal fuel, preferably in the form of the coal dust, fed into the said gasifier, is gasified while producing a gaseous product in the form of a carbon monoxide (CO) according to the oxidation reaction equation

(2) C + ½0 2 CO. while producing a mass stream of contaminated carbon monoxide which is then fed to the thermal energy recovery sub-process. In the embodiment of the invention the method is further characteristic by that, in the thermal energy recovery sub-process a hot mass stream of contaminated carbon monoxide (CO) having a temperature ranging from 1050°C to 1150°C, preferably 1100°C, from the coal fuel gasifier flows into the heat exchanger included in the installation of said sub-process, in which said heat exchanger it is cooled to a temperature in the range from 645 to 655°C, preferably to 650 C, obtaining thermodynamic parameters of the cooled mass stream of contaminated carbon monoxide having a temperature, preferably and a pressure ranging from 2.45 to 2.55 MPa, preferably 2.5 MPa, and then it is directed to the gas purification sub process, wherein to the second heat exchanger, which is a part of the technological installation of the thermal energy recovery sub-process, the hydrogen mass stream is also directed and flows into it, which hydrogen mass stream exiting from the high-temperature electrolysis sub process, in particular coming out from a compressor, to the input of which flows the hydrogen mass stream having a pressure in the range from 2.9 to 3.1 MPa, preferably 3.0 MPa, and a temperature in the range from 850 to 950°C, preferably 900°C, which comes out from the high-temperature electrolyser, and from the exit of which compressor the hydrogen mass stream having a pressure in the range from 3.4 to 3.6 MPa, preferably 3.5 MPa flows out, and then in the heat exchanger the said hydrogen mass stream is cooled to a temperature in the range from 645°C to 655°C, preferably 650 ^° C, and throttled to a pressure in the range from 2.45 MPa to 2.55 MPa, preferably 2.5 MPa, to obtain a state of thermodynamic parameters of the hydrogen mass stream, wherein both said mass streams, i.e. the cooled mass stream of contaminated carbon monoxide and the hydrogen mass stream are separately directed to the gas purification sub-process by means of separate supply conduits, and wherein additionally simultaneously, in said heat exchangers of the energy recovery sub-process installation, a high pressure steam is generated in the form of a high pressure steam mass stream that is directed therefrom to the steam turbine in the technological installation of the coal gasification and electric energy generation sub-process, which the stream turbine is connected to and powering the power generator, in which the electric energy for the transmission line is generated.

In the embodiment of the invention the method is further characterized by both said separate mass streams, namely: the carbon monoxide and the hydrogen mass streams, that are components of the synthesis gas, after exiting the gas purification sub-process in the form of the pure carbon monoxide mass stream, having a temperature 330 ^° C and a pressure 2.2 MPa, and the hydrogen mass stream, having a temperature 340°C and a pressure 2.2 MPa, are directed to the synthesis gas production sub-process, namely through control check valves of mass stream value, respectively, a control check valve of the carbon monoxide mass stream and a control check valve of the hydrogen mass stream, and then through mass stream flowmeters connected to them, respectively, a carbon monoxide mass stream flowmeter and a hydrogen mass stream flowmeter, which said flowmeters are connected upstream the input of the mixing converter, flow into this mixing converter, in which after mixing the both said components of the synthesis gas, carbon monoxide (CO) with the hydrogen (¾) in the molar ratio ricomm » 1:2,12, the synthesis gas is produced having a temperature in the range of 330 ^° C and a pressure in the range of 2.2 MPa, and having the form of the outlet synthesis gas mass stream.

In the embodiment of the invention the method is further characteristic by two negative feedback systems, that are provided to meet the condition of achieving the said molar ratio of carbon monoxide (CO) to hydrogen (H2) n _C0 :nH2 » 1:2,12 in the mixing converter and to produce the output synthesis gas mass stream, said two negative feedback systems, preferably, transmit a signal from the flowmeter incorporated into the carbon monoxide supplying conduits about the measured, current value of the carbon monoxide (CO) mass stream, and a signal from the flowmeter incorporated into the hydrogen (H2) supplying conduits about the measured, current hydrogen mass stream value, to the transducer of feedback control signals which the said transducer processes them according to the pre-set condition of the molar ratio n _o unin » 1:2,12 into actuating signals, preferably electric, i.e. an actuating control signal for carbon monoxide and an actuating control signal for a hydrogen, respectively, by means of which actuating signals the check valve controlling the value of the carbon monoxide mass stream and the check valve controlling the hydrogen mass stream value, respectively, are controlled, which both said check valves are connected upstream of the mixing converter with respect to the gas flow direction.

In the embodiment of the invention the method is further characteristic by that, the oxygen O2 is produced in the high-temperature electrolysis sub-process, in a set of electrolysers comprising at least one or more high-temperature electrolysers, in the form of the total oxygen mass stream, wherein a part of said total oxygen mass stream in the form of the oxygen mass stream of a value equal to, preferably, a half of the total amount of the oxygen in the total oxygen mass stream produced in this said electrolysis process, is delivered to the coal fuel gasification sub-process in a controlled manner by means of the check valve, and it is used to gasify the coal fuel in the coal fuel gasifier. According to the invention a system is provided for producing electric power and a synthesis gas from a coal fuel by the above-described method for producing electric power and a synthesis gas from a coal fuel by means of the emission-free coal-nuclear synergy technology, which coal fuel is gasified in an oxygen, comprising the technological installation of a coal fuel gasification sub-process containing the coal fuel gasifier, preferably a flow gasifier, connected to a coal fuel supply installation, an oxygen and a water supply installations, an electric power generating installation comprising at least one gas turbine coupled to a current generator, an outlet installation for discharging a gaseous product, preferably in the form of a gas mass stream, produced in the coal fuel gasifier, a technological installation of the thermal energy recovery sub-process, being equipped with at least one heat exchanger, and preferably at least two heat exchangers, a technological installation of the sub process for purification of a gas produced in the coal fuel gasification sub-process in at least one gasifier, said installation is equipped with a cyclone filter, a water scrubber, a condenser and the Rectisol process technological installation, Claus process technological installation, SCOT process technological installation and technological installation of dehydration process (TEG), the said system further comprises a technological installation of the high-temperature water-splitting electrolysis sub-process comprising at least one or more high-temperature electrolysers powered by electric energy generated by at least one nuclear reactor coupled to at least one or more heat exchanger, a gas turbine and a current generator, and said installation of high-temperature electrolysis sub-process further comprises, respectively, at least two units, one for discharging the oxygen mass stream to the installation of the gasifier and the other one for discharging the hydrogen mass stream to the installation of the energy recovery sub process, in particular to the heat exchanger and subsequently to the technological installation of the gas purification sub-process, the said system being characteristic by it further comprises a technological installation of the sub-process for producing synthesis gas, said installation comprising a mixing converter of synthesis gas in which a synthesis gas is produced and to which a pure carbon monoxide mass stream is fed, through the monoxide supply conduits, and a hydrogen mass stream from the gas purification sub-process is supplied, wherein furthermore in the unit for discharging total oxygen mass stream from one or more high- temperature electrolyser the compressor is incorporated, in which the said oxygen mass stream is divided into two output oxygen mass streams, wherein the one of output oxygen mass streams being throttled by means of a check valve, connected to the oxygen supply conduit supplying oxygen to the gasifier, which check valve operates in a negative feedback system in cooperation with, being in a signal communication to it, said carbon dioxide sensor, generating an electric feedback signal informing about detection of the presence of carbon dioxide (CO2) in gaseous products of a coal gasification, in the amount exceeding the pre-set upper limit value in the mass stream of gaseous products of said coal fuel gasification, and transmitting the said signal to the feedback actuating electric signal transducer, connected to it by means of a signal communication, that said transducer generates the actuating control signal, which is transmitted to the said check valve connected to it in a signal communication manner, which check valve regulates the current value of the oxygen mass stream supplying the coal fuel gasifier in such a way that the coal fuel is gasified only while producing carbon monoxide (CO) as a gaseous product of the coal fuel gasification.

In the embodiment of the invention the system is further characterized by the technological installation of the synthesis gas production sub-process, including the synthesis gas mixing converter that installation comprises separate supplying conduits, respectively one for delivering of the pure carbon monoxide mass stream and the other one for delivering of the hydrogen mass stream, which said conduits are in fluid communication with the installation of the gas purification sub-process and to which conduits, upstream the input to the mixing converter, a control check valve of a pure carbon monoxide mass stream and a control check valve of a hydrogen mass stream are connected respectively, and further connected to them a carbon monoxide mass stream flowmeter and a hydrogen mass stream flowmeter, respectively, which said flowmeters are connected to a transducer by way of a signal communication which transducer converts feedback signals, respectively one corresponding to the hydrogen and one corresponding to carbon monoxide mass stream values, transmitted from the said flowmeters for the hydrogen mass stream and the carbon monoxide mass stream, respectively, into the actuating control signals, each directed to the respective control check valves, i.e. to the control check valve of the hydrogen mass stream and the control check valve of the carbon monoxide mass stream, in order to deliver to the inlet of the mixing converter controlled mass streams, that is the hydrogen mass stream and the pure carbon monoxide mass stream, having desired thermodynamic parameters and the desired molar ratio one to another for the Fischer-Tropsch coal fuel liquefaction process.

In the embodiment of the invention the system is further characterized by the nuclear reactor provided in the installation of the high-temperature electrolysis sub-process, that is the high-temperature helium-cooled Generation IV nuclear reactor, wherein said nuclear reactor is connected by a conduit system with a heat exchanger and preferably two additional heat exchangers in the helium circulation closed circuit of the helium mass stream and further helium mass streams for cooling the reactor core, which helium mass stream is heated in the reactor core to a temperature of more than 1000 ^° C, preferably 1060 ^° C, wherein conduits are connected at the outlet of the heat exchanger for discharging, respectively, the high- temperature steam produced in this heat exchanger, that is then fed to at least one high- temperature electrolyser and the high pressure steam, that is fed to a steam turbine through a heat exchanger, wherein the steam turbine is coupled with a current generator, from which the electric current is supplied to at least one high-temperature electrolyser.

In the preferred embodiment of the high- temperature electrolysis sub-process installation at the input of the heat exchanger mentioned above, the water cooling the helium mass stream flows into the inlets to the heat exchanger, preferably two inlets, to form at the exit of the said heat exchanger the high pressure steam mass streams and the high-temperature steam mass streams, respectively, where the high-temperature steam mass stream is directed to the high-temperature electrolyser, and the high pressure steam mass stream is directed to the heat exchanger which cools the high-pressure steam mass stream to meet desired parameters of a state of high pressure steam, which in combination with the high pressure steam mass stream, created in the heat exchanger as a result of the absorption of the heat flux coming from the high-pressure steam mass stream by said water mass stream, form together a high-pressure steam mass stream, which in combination with the earlier mentioned high pressure steam mass stream, which was created as the result of cooling of the helium mass stream in the heat exchanger by means of the water mass stream supplied therein, form together a high pressure steam mass stream supplied to and feeding the steam turbine.

The invention also proposes the use of the above described inventive method and the above described system for generating electric energy and synthesis gas, to produce synthetic liquid fuel from a coal fuel by means of the Fischer-Tropsch process in the technological installation of the Fischer-Tropsch sub-process, wherein said installation contains at least one Fischer-Tropsch reactor and in which installation synthesis gas in the form of a synthesis gas output mass stream exiting from the mixing converter is fed to at least one said Fischer- Tropsch reactor and is converted to a methanol CH ₃ OH, in accordance with the catalytic reaction (1) (2n + l) ₂ + nCO ® C _n H _{2n+ 2} + nH ₂ 0, where n is a natural number, preferably whithin the limits from 1 to 42.

In the embodiment of the invention the use is further characterized by, an installation of the heat recovery and electric energy production sub-process from the mass stream of the output gas leaving the Fischer-Tropsch process, that is connected to the technological line of the Fischer-Tropsch sub-process, in which said installation the units of the electric energy generator and the electric energy generator are incorporated and connected producing electric current by using the mass stream of the output gas, preferably for supplying the technological installation of the high-temperature electrolysis sub-process, in particular at least one high- temperature electrolyser.

According to the invention it is also or additionally proposed a use of the method according to the invention mentioned above and the system according to the invention mentioned above for producing synthesis gas in the methane oxidation sub-process by Catalytic Partial Oxidation (CPOx) method, in which a methane mass stream, preferably derived from demethanization of a mine, as well as the oxygen mass stream produced in the high-temperature electrolysis sub-process are directed and flow into a catalytic methane oxidation (CPOx) reactor, in which in the methane oxidation reaction the synthesis gas is produced forming the synthesis gas mass stream, which has a temperature in the range from 740 ^° C to 760 ^° C, preferably 750 ^° C and a pressure in the range from 2.8 to 3.0 MPa, preferably 2.9 MPa, which is then cooled and subjected to pressure regulation to obtain parameters of a state of the synthesis gas mass stream having a temperature in the range from 330 ^° C to 350 ^° C, preferably 340 ^° C, and a pressure in the range from 2.1 to 2.3 MPa, preferably 2.2 MPa, said use being characterized by the synthesis gas mass stream, coming out from the installation of the methane oxidation sub-process that is directed to the said installation of the synthesis gas production sub-process, containing the mixing converter where the synthesis gas mass stream is produced, wherein the oxygen mass stream, as a part of the stream obtained from the oxygen mass stream produced in the high-temperature electrolysis sub-process, is fed to the installation of the methane oxidation sub-process, which oxygen mass stream has a value equal to a half of the value of the total oxygen mass stream produced in the high-temperature electrolysis sub-process.

The method according to the invention is characterized in particular by the fact that in the provided synthesis gas production process, the two main components of synthesis gas, i.e. a carbon monoxide (CO) and a hydrogen (¾) are produced separately in separate method steps forming sub-processes of the synthesis gas and electrical power production process according to the invention, wherein carbon monoxide (CO) is produced in the coal fuel gasification in oxygen sub-process while hydrogen (¾) is produced in the high-temperature electrolysis sub-process, wherein both said sub-processes being carried out in emission-free technology, i.e. without carbon dioxide (CO ₂ ) and nitrogen oxides (NO _x ) emission.

According to the subject matter of the invention, in the coal fuel gasification sub process the coal fuel is gasified i.e. subjected to gasification in an oxygen (O ₂ ) in a modified coal fuel gasification installation according to the invention solely to a carbon monoxide (CO), while the second component of the synthesis gas - hydrogen (¾) - is produced in the high-temperature electrolysis (HTES) sub-process, preferably solid-oxide process using heat, in particular in the form of high-temperature steam, and electric power generated by using a helium-cooled high-temperature IV-Generation nuclear reactor, whereas an oxygen (O ₂ ) which is simultaneously produced in the high-temperature electrolysis sub-process is used to supply the coal fuel gasification in oxygen sub-process in the modified coal fuel gasification installation according to the invention while producing a gaseous product containing approximately only carbon monoxide (CO).

According to the preferred embodiment of the invention, oxygen (O ₂ ) and hydrogen (H2) are obtained by way of water-splitting in the high-temperature electrolysis sub-process (HTES), wherein the oxygen O ₂ produced in said high-temperature electrolysis sub-process in an amount equal to a half of the total amount of the oxygen produced in this high-temperature electrolysis sub-process is supplied instead of the air and used for gasification of a coal fuel in the modified coal fuel gasification installation or alternatively for coal combustion in a combustion chamber of a modified coal-fired power plant, which modified coal fuel gasification installation comprises a control system for controlling the coal fuel gasification process in such a way that whole coal fuel gasified in the presence of the supplied oxygen O2 is consumed during the production of an appropriate amount of thermal energy, only to form a gaseous product in the form of carbon monoxide (CO) according to the combustion reaction equation

(2) C + ½0 2 CO.

Whereas the rest of produced in the high-temperature electrolysis sub-process oxygen amount, equal to a half of the total amount of oxygen total production, can be used as a final product for consumers or is utilized in any different manner, in a preferred application of the invention e.g. for producing synthetic liquid fuel in the Fischer-Tropsch process or alternatively or additionally in the methane oxidation process. The hydrogen (¾) produced in the high-temperature electrolysis sub-process (HTES) together with the carbon monoxide (CO) produced in the coal fuel gasification sub process in the technological installation for coal fuel gasification according to the invention in line with the above combustion reaction (2) are mixed together in the mixing converter and form synthesis gas (2H2 + CO) constituting its main components, i.e. substrates in the synthesis gas production process, which synthesis gas, preferably in the embodiment of the invention, can be utilized as a substrate for a production of synthetic liquid fuels in accordance with the known catalytic reaction (1) described hereinafter.

In the emission-free coal-nuclear synergy technology ( BSWJ) presented in accordance with the present invention, the final production of synthesis gas in the embodiment of the invention, preferably, takes place in the synthesis gas mixing converter according to the invention in the mixing process of the carbon monoxide (CO) mass stream produced in the coal power plant for gasification of a coal fuel in oxygen in the coal fuel gasifier or combusting it in oxygen according to the invention in accordance with the Pulverized Coal Combustion (02PCC) technology modified according to the invention in such a manner that a coal fuel is gasified or combusted solely to carbon monoxide (CO) as a gaseous product of gasification or combustion of coal fuel and of the hydrogen (¾) mass stream produced in a solid-oxide high-temperature electrolyser. The said mixing converter is connected to a molar ratio control system of controlling the content of carbon monoxide and a hydrogen in the synthesis gas mixture produced according to the invention to obtain the synthesis gas having desired parameters, a pressure about 2.2 MPa, a temperature about 330 ^° C and a corresponding molar ratio of H2 to CO, in the approximate range n^/nco = 2.12: 1, and it replaces the known Lurgi reactor that is described in the prior art in the Fischer- Tropsch process technology for producing synthetic fuels. Production of synthesis gas in the synthesis gas mixing converter according to the invention by the emission-free coal-nuclear synergy technology ( BSWJ) is much simpler from a technical point of view and thus significantly cheaper.

Brief Description of the Drawings

The system and the method for emission-free production of electric power and synthesis gas from a coal fuel in an zero-emission coal-nuclear synergy technology, preferably without carbon dioxide emission to the atmosphere and its application in the embodiment examples of the invention are presented in the attached drawing, in which: Fig. 1 shows schematically in a simplified manner a synthesis gas and liquid fuels production system by a coal fuel liquefaction process according to the closest prior art;

Fig. 2 shows schematically the system and the method for generating electric power and a synthesis gas in one embodiment of the invention, wherein the illustrated scheme includes the known Fischer-Tropsch installation for producing liquid synthetic fuels from a synthesis gas, as an example of using of the system and the method according to the invention; and

Fig. 3 shows schematically the system and the method for generating electric power and a synthesis gas from a coal fuel according to the invention of fig. 2, wherein as an example of using the system and the method according to the invention, the known in the art installation used for oxidation of a methane is additionally shown.

Description of embodiments.

Detailed description of the process and technological installation (the system) according to the invention is shown on the basis of an exemplary embodiment of the method for producing electric power and synthesis gas from coal fuel in the emission-free coal- nuclear synergy technology (BSWJ) without carbon dioxide emission to the atmosphere, in particular together with the presentation of preferred examples of the application of the invention used further for producing synthetic liquid fuels.

According to the invention, the term "mass stream" as used herein is understood a mass resource of a given gaseous or liquid substance flowing per unit of time, wherein the mass stream in the SI system is expressed in unit [kg/s].

For example, according to the invention, there are mentioned following mass streams-: carbon monoxide-, oxygen-, hydrogen-, synthesis gas-, high-pressure steam-, high- temperature steam-, and medium pressure steam-, water-, methane-, etc.

(Mass stream = mass resource/time = dm/dt)

Additionally, the term "mass resource" in accordance with the invention and in accordance with the present description should be understood as a "resource" as the primary term constituting an "extensive quantity", wherein the "extensive quantity" (EQ) is called such physical or geometric quantity whose resource in the area consisting of the sum of sub- areas is equal to the sum of resources in all sub-areas. Simultaneously, the term "synthesis gas" is understood herein as a mixture of hydrogen and carbon monoxide (2H2+CO).

The process (UPW) II-OO for producing electrical energy and a synthesis gas from a coal fuel gasified in an oxygen in the emission-free (zero-emission) coal-nuclear synergy technology, preferably free from the emission of carbon dioxide into the atmosphere according to the invention and further, preferably, subsequently liquefied, consists of many sub-processes occurring within the process (UPW) 11-00 such as: a coal fuel gasification sub process II-IO by which a gaseous product is produced, which is one component of synthesis gas, particularly the carbon monoxide, with simultaneous production of electric energy, a heat energy recovery sub-process 11-20, a sub-process 11-30 for purifying gas which is in the form of contaminated carbon monoxide, high-temperature electrolysis sub-process III-00, synthesis gas production sub-process 11-40, wherein the solution according to the invention may include, alternatively or additionally, as the application of the process (UPW) II-OO, the Fischer-Tropsch sub-process 11-60 following the synthesis gas production sub-process 11-40, a thermal energy recovery and production of electric energy sub-process 77-90 and, preferably, it may alternatively or additionally be supplemented with a methane oxidation sub-process IV-00. Each of the sub-processes being component sub-processes of the process (UPW) 77-00 for producing electric energy and synthesis gas from coal fuel gasified in oxygen according to the invention and, in the embodiment of the use of the invention preferably liquefied, is schematically illustrated in fig. 2, which schematically shows the technological installations for implementation individual sub-processes, interconnected one to each other by a suitable connection system of conduits enabling a flow of a fluid or energy within the system according to the invention, in a way illustrating flow of mass- and energy streams, wherein the individual sub-processes and their respective technological installations are shown as separated by dashed lines for clarity. The process (UPW) II-OO for producing electric energy and synthesis gas from a coal fuel gasified in oxygen according to the invention is described with reference to the known prior art described in the process (UPW) 1-00 for coal fuel liquefaction and illustrated schematically in fig. 1 or, for example, in the above-mentioned by way of reference the patent publication No. US 2008/0103220A1, in its initial part concerning the description of the closest prior art for coal fuel liquefaction.

Technological installation for operating sub-process II-IO for gasification a coal fuel and producing electric energy while forming gaseous product, which according to the invention is a carbon monoxide (CO) (contaminated), being a step of the process (UPW) II- 66 for producing electric power and synthesis gas from a coal fuel, especially gasified in oxygen, includes in a preferred embodiment, in particular, one or more dryers 11-12, a dust mill 11-14, a coal fuel flow gasifier 77-26, a heat exchanger 77-17 for producing, preferably, a high-pressure steam 6, steam turbines 77-79a and II-19b, preferably coaxial and concurrent (co-rotating), coupled to and driving the current generator Gl. The following devices connected one to another by signal transmitting connection: carbon dioxide sensor 11-18 generating a signal II-I8s, preferably electronic, a converter II-psl for converting said electronic signal II-18s from the carbon dioxide sensor II-18 to a feedback signal II-18ps, preferably electric, transmitted to a check valve 777-5 for controlling the current value of the oxygen mass stream III-8a, that is produced and supplied from high-temperature electrolysis sub-process III-00, which will be discussed in the following description, to the flow gasifier 11-16. The coal fuel 77-77 used in the coal fuel gasification and production of electric energy sub-process 11-10 while forming gaseous product, being roughly solely only a carbon monoxide (CO), is supplied initially to one or more dryers 11-12 in order to reduce the moisture content in the coal fuel 77-77. A moisture removed from the coal fuel 77-77 is removed from the dryer 11-12. The dryer or driers 11-12, in a preferred embodiment, may comprise a heat exchanger or may comprise other conventional typical drying processes appropriate for the process ( UPW) 77-00 for producing electric energy and synthesis gas from the coal fuel gasified in an oxygen. The coal fuel 11-13 after being dried in the above described drying sub-process 11-13 is supplied to a grinding device, preferably a dust mill II- 14, where the dried coal fuel 11-13 is crushed and ground, or otherwise reduced to the appropriate size suitable for the coal fuel gasification process. The crushed and ground coal fuel 77-75 is supplied to a coal fuel gasification device, preferably in the form of a coal fuel flow gasifier 77-7 , where the coal fuel is gasified. The coal fuel gasification apparatus, in the embodiment of the invention the coal fuel flow gasifier 77-76, is supplied with a half of the oxygen mass stream 777-5, in the form of the mass stream 77-56, having temperature in the range from 850°C to 950°C, preferably 900°C, which is produced, preferably, in the high- temperature electrolysis sub-process 777-66 in high-temperature electrolysers HI-4, then is compressed to a pressure in the range from 3.4 MPa to 3.6 MPa and preferably 3.5 MPa in a compressor III-12 and subjected to regulation in terms of the supplied oxygen mass stream HI-8a range, preferably by using of the check valve 777-5 regulating values of an oxygen mass stream, being in fluid communication to the gasifier 77-76, which said oxygen mass stream IH-8a is then supplied to the flow gasifier 77-76. After said crushing and/or grinding process, the coal fuel mass stream 11-15 is subjected to gasification, preferably in the coal fuel flow gasifier 11-16 in the oxygen mass stream III-8a, at the pressure in the range from 2.85 to 2,95 MPa, preferably about 2.9 MPa, and the temperature in the range from 1050 to 1150°C, preferably 1100°C. A water tank (ZW) is connected to the coal fuel gasification installation, preferably comprising a flow gasifier 77- 16. The water from the water tank (ZW), forming the water mass stream 2, flows through the heat exchanger 11-17 located inside the coal fuel flow gasifier 11-16, in which said heat exchanger 11-17 said water 2 reaches a phase of super heated high-pressure steam 6 having the temperature in the range from 610 to 630° C, preferably approximately 620° C, and the pressure in the range from 29.5 to 30.5 MPa, preferably 30 MPa, which then is directed to the entry of the steam turbine II-19a. The gasification of the crushed and ground coal fuel 17-25, preferably coal dust, in the coal fuel flow gasifier 77-76 according to the invention is carried out in such a way that solely carbon monoxide (CO) is produced, i.e. only the carbon monoxide is produced as the gaseous product of the gasification as a result of gasification of said coal fuel in the flow gasifier 77-76, wherein the produced carbon monoxide (CO) mass stream II-16a having pressure ranging from 2.85 MPa to 2.95 MPa, preferably 2.9 MPa and the temperature ranging from 1050 to 1150°C, preferably 1100°C, flows out from the sub process 77-76 for a coal fuel gasification and electric energy production and flows into the subsequent thermal energy recovery sub-process 11-20, where it is directed to the heat exchanger 77-22, in which the water mass stream 2 supplied from the water tank (ZW) cools the carbon monoxide (CO) mass stream II-16a while producing high-pressure steam mass stream 6 having the temperature in the range from 610° C to 630° C, preferably 620° C, and the pressure in the range from 29.5 MPa to 30.5 MPa, preferably 30 MPa, which the high- pressure steam mass stream 6 is directed again to the coal fuel gasification and electric energy production sub-process 77-76, supplying the steam turbine II-19b located there in a known manner, preferably coupled coaxially and concurrent (co-rotating) to said steam turbine 77- 19a, which both steam turbines II-19a, II-19b drive the current generator G1 generating, in the known way, electric energy for commercial purposes, which is directed to consumers supplied by this coal-fired power plant, which gasifies a coal fuel in an oxygen by means of the flow gasifier 77-76. The coal fuel flow gasifier 77-76 also produces a slag a mass stream 77-766 of which is removed from the said gasifier in a known manner. The medium pressure steam 4 having the pressure in the range from 7.4 MPa to 7.6 MPa, preferably 7.5 MPa, and the temperature in the range from 320 to 340°C, preferably 330 ^° C, which flows out from the steam turbines II-19a and 77-796 can be used anywhere in the further process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel. The hot carbon monoxide mass stream II-16a from the coal fuel gasification sub-process II-IO having the pressure in the range from 2.85 to 2.95 MPa, preferably 2.9 MPa and the temperature in the range from 1050°C to 1150°C, preferably 1 100°C, flows into the heat energy recovery sub-process 77-29 and is directed to the said heat exchanger H-22 in which it is cooled by the water mass stream 2 from the water tank (ZW) from the temperature ranging from 645 to 655°C, preferably 650°C and throttled starting from the pressure 2.45 to 2.55 MPa, preferably 2.5 MPa, to form a carbon monoxide mass stream H-23.

According to the solution of the invention illustrated in the embodiment in fig. 2, in the coal fuel gasification and electric energy production sub-process 11-10 which is one of steps of the process (UPW) 11-00 for producing electric power and synthesis gas from a coal fuel gasified in an oxygen, in relation to the coal fuel liquefaction process (UPW) 1-00 describing the prior art mentioned and described earlier and illustrated in fig. 1 or, for example, according to the US 2008/0103220 patent in its preamble part concerning the description of prior art art in the coal fuel liquefaction process, the system for producing synthesis gas and electric energy from coal fuel has been changed in such a way that the coal fuel 11-15 supplying the flow gasifier is subjected to gasification in this flow gasifier 11-16 only to a carbon monoxide (CO) as a gaseous product, in the oxygen in the form of an oxygen mass stream III-8a supplying the flow gasifier HI-16 to produce the first component of the synthesis gas - carbon monoxide (CO), moreover, the heat exchanger 77-77, which is connected to and arranged inside the flow gasifier 11-16, supplied with the water mass stream 2 from the water tank (ZW), produces high-pressure steam 6, which is also produced in the thermal energy recovery sub-process 77-20, and both high-pressure steam mass streams 6 are directed and supply the set of concurrent and coaxial steam turbines ll-19a and 77-790, which are coupled to and drive the electric current generator G1 producing electric energy to the transmission network.

Furthermore, according to the subject matter of the invention, in one of the embodiment illustrated, for example in fig. 2, in the coal fuel gasification and electric energy production sub-process 77-79, the coal fuel gasifier 77-76 in comparison to the prior art coal fuel gasifier, for example 1-16 of the coal fuel gasification sub-process 1-10 of the coal fuel liquefaction process (UPW) 1-00 illustrated in fig. 1, or for example, according to the US2008/01093220 patent in its preamble part concerning the description of the prior art coal fuel liquefaction, has been equipped with a heat exchanger 77-77 for producing high- temperature and high-pressure steam 6 produced from a water mass stream 2 feeding this said heat exchanger and supplied from the water tank (ZW), as described above but, in addition, no any steam is supplied to the coal fuel gasifier Ii-16.

According to the subject matter of the invention, illustrated in the exemplary embodiment of fig. 2, in the coal fuel gasification and electric energy production sub-process 11-10, in contrast to the known prior art, for example of the gas gasification sub-process 1-16 of the coal fuel liquefaction process (UPW) 1-00 illustrated in fig. 1, the coal fuel gasifier II- 16 is equipped with a carbon dioxide detector II-18 for detecting the presence of a carbon dioxide in gaseous product(s) of the coal fuel gasification process, consisting mainly of contaminated carbon monoxide. Furthermore, according to the invention, illustrated by way of an example, in the embodiment of fig. 2 in the coal fuel gasification and electric energy production sub-process II-10, the coal fuel gasifier 11-16, in contrast to the known coal fuel gasifier 1-16, is fed neither by the steam mass stream 0 nor by water mass stream 2, and hence does not produce any mass streams of synthesis gas, a hydrogen, a carbon dioxide and a medium pressure steam 4, and only produces a mass stream of gaseous (a gas) product consisting essentially, solely of a carbon monoxide, in particular the contaminated carbon monoxide mass stream, with admixtures of contaminants, including gases, as well as solid and liquid contaminating particles, from which contaminants the contaminated carbon monoxide mass stream is then purified in the subsequent gas purification sub-process II-30.

According to the invention, in the preferred embodiment illustrated for example in fig. 2, in the coal fuel gasification and electric energy production sub-process II-IO, the coal fuel gasifier 11-16, in contrast to the above-mentioned prior art, is not supplied with an oxygen mass stream derived from cryogenic separation of air into an oxygen and a nitrogen, but it is supplied with the oxygen mass stream III-8a, which is fed to the technological installation of the coal gasification and electric energy production sub-process II-IO from high-temperature electrolysers III-4 producing an oxygen and a hydrogen in the water splitting electrolysis reaction and included in the technological installation for implementation of the high-temperature electrolysis sub-process III-OO.

In the embodiment of the invention illustrated by way of the example in fig. 2 two coaxial and co-rotating turbines II-19a and II-19b in the coal fuel gasification and electric energy production process II-IO are preferably installed in comparison to the prior art illustrated in fig. 1 for driving the power generator G1 that produces electric current to the public transmission network without emissions of CO2 to the natural environment.

According to the invention, in the embodiment of the invention illustrated in fig. 2 in comparison to the prior art illustrated in fig. 1 in the coal gasification and electric energy production sub-process 11-10 the technological installation for conducting the coal fuel gasification and electric energy production is equipped with a feedback signal transducer 77- psl, preferably electrical, to receive a signal II-18s, preferably electronic, sent by a carbon dioxide sensor II-18 connected to it by a signal communication and which sensor 11-18 is installed at the outlet of the flow gasifier 11-16, and further generating the actuating signal II- 18ps, preferably electric, which is supplied via a signal communication connection to the check valve III-5 and initiates the operation of it to regulate the value of the oxygen mass stream III-8a for feeding the coal fuel flow gasifier II-16 in such a way that the coal fuel II- 15 supplied to the gasifier II-16 is gasified or preferably burned only to carbon monoxide (CO) as a gaseous product (a gas) of the coal gasification process.

Unlike the prior art, according to the subject matter of the invention, in the embodiment of the invention illustrated in fig. 2, in the coal fuel gasification and electric energy production sub-process II-IO, the coal fuel gasifier 11-16 is used, which, in contrast to known gasifiers, including the coal fuel gasifier from the coal gasification sub-process 1-10, for example according to the US 2008/0103220 patent in its preamble part concerning the description of the known state of the art in the coal fuel liquefaction, gasifies the coal fuel II- 15, and preferably a coal dust, roughly solely to a carbon monoxide (CO) as a gaseous product of gasification, in the presence of the oxygen produced in the sub-process III-00 of the high-temperature electrolysis in the form of the oxygen mass stream IH-8 having a temperature ranging from 850 ^° C to 950 ^° C, preferably about 900 ^° C and a pressure from 2.95 to 3.05 MPa, preferably 3 MPa, wherein said oxygen is then compressed in the compressor HI- 12 to a pressure in the range from 3.4 MPa to 3.6 MPa, preferably 3.5 MPa and divided into two output oxygen mass streams III-8a, III- 8b, wherein the oxygen mass stream III-8a is throttled by means of the check valve 7/7-5 operating in a negative feedback system in cooperation with the carbon dioxide sensor H-18 emitting the feedback signal H-18s, preferably electronic, informing about the detection of the presence of a carbon dioxide (CO2) in the gaseous product of the coal gasification exceeding the pre-set upper content limit of 0.1% of the total mass stream value of the gaseous products of the coal gasification process, and transmitting the signal to the feedback actuating electric signal transducer II-psl connected to it by way of a signal communication connection, that said transducer generates the actuating control signal II-18ps, preferably electric, directed to the check valve HI-5, connected to the oxygen supply line to the gasifier II-16, which valve HI-5 controls the current value of the oxygen mass stream HI-8a supplied to and feeding the oxygen to the coal fuel flow gasifier 11-16 in such a way that the coal fuel H-15, preferably the coal dust, is gasified solely to a carbon monoxide (CO) as the gaseous product of the coal fuel gasification.

In the thermal energy recovery sub-process 11-20 being a step of the process (UPW) H-0 for producing electric power and a synthesis gas from a coal fuel gasified in oxygen, which preferably may be subsequently liquefied, the hot mass stream H-16a of the gaseous product in the form of contaminated carbon monoxide (CO) having the temperature in the range from 1050° C to 1150°C, preferably 1100°C flowing out from the gasifier 11-16 flows then into the heat exchanger 11-22, where it is cooled to a temperature in the range from 645°C to 655°C, preferably to temperature of 650°C. The cooled mass stream 11-23 of contaminated carbon monoxide at the temperature preferably within limits of 650° C and under the pressure in the range from 2.45 to 2.55 MPa, preferably 2.50 MPa is directed to the gas purification sub-process 11-30.

The water stream 2 coming out from the water tank (ZW) can be also fed by way of a fluid communication to the heat exchanger 11-22, which is included in the technological installation of the thermal energy recovery sub-process H-20. The water mass stream 2 absorbs thermal energy in the heat exchanger H-22 to form a high-pressure steam mass stream 6. The high-pressure steam mass stream 6 produced in the heat exchanger II-22 is directed to supply the steam turbine II-19b in the coal fuel gasification and electric energy production sub-process 11-10. To another one heat exchanger II-22a, also included in the installation of the thermal energy recovery sub-process H-20, the hydrogen mass stream III- 10a coming out from the high-temperature electrolysis sub-process HI-00 is also directed and flows into it, and precisely flowing out of the compressor HI-14 to which the hydrogen mass stream HI-10 flows from at least one high-temperature electro lyser III-4, wherein the hydrogen mass stream III-10 having a temperature in the range of 850 ^° C to 950 C, preferably 900°C and the pressure ranging from 2.9 to 3.1 MPa, preferably 3.0 MPa, which then flows into the compressor IH-14 where it is compressed to a pressure in the range from 3.4 to 3.6 MPa, preferably 3.5 MPa and having a temperature in the range from 850 to 950°C, preferably 900°C to form the hydrogen mass stream IIl-10a, where said hydrogen mass stream is subsequently cooled in a heat exchanger H-22a, preferably to a temperature of about 650 ^° C at a pressure of about 2.5 MPa to form a hydrogen mass stream III-10d, that flows out from the heat exchanger II-22a. The heat exchanger II-22a is also supplied with the water mass stream 2, to which it is supplied from the tank (ZW) and from said water in this heat exchanger II-22a a high-pressure steam mass stream 6 is produced having a temperature in the range from 610 to 630 °C, preferably 620 ^° C and a pressure in the range from 29.5 to 30.5MPa, preferably 30 MPa to feed previously mentioned steam turbine II-19b in the installation of the coal fuel gasification and electric energy production sub-process 11-10. Comparing the thermal energy recovery sub-process II-20 of the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen according to the invention with the gas and thermal energy recovery sub-process 1-20 of the process (UPW) 1-00 for coal fuel liquefaction describing known state of the art (fig. 1) or, for example, according to the US 2008/0103220 patent in its preamble part concerning the description of the prior art in the area of coal fuel liquefaction, the following differences should be emphasized.

In contrast to the thermal energy recovery sub-process of the coal fuel liquefaction process (UPW) 1-00 according to the above-mentioned prior art, referring to the subject matter of the invention, according to the embodiment of the invention, in the thermal energy recovery sub-process II-20, in the heat exchangers 11-22 and II-22a used in its technological installation according to the invention, there is a change in the steam production process consisting in the production of high-pressure steam 6 only while the medium pressure steam 4 is produced in the additional heat exchanger II-40a located in the gas purification sub-process 11-30, which will be described in more detail later.

In contrast to the prior art, for example presented in the embodiment of the coal fuel liquefaction process (UPW) 1-00 illustrated in fig. 1, according to the invention, in one embodiment of the invention, in the thermal energy recovery sub-process 11-20, in the heat exchanger II-22a used according to the invention, the hydrogen mass stream III-10a having a temperature in the range of 850 ^° C to 950 ^° C, preferably 900 ^° C and a pressure in the range from 3.4 to 3.6 MPa, preferably 3.5 MPa is cooled to a temperature in the range from 645°C to 655°C, preferably 650°C and throttled to a pressure in the range from 2.45 MPa to 2.55 MPa, preferably 2.50 MPa, to obtain the state of thermodynamic parameters of the hydrogen mass stream Ill-lOd, which is further directed to the installation of the gas purification sub-process 11-30. The sub-process 11-30 for purification of the gas produced in the process (UPW) II-O for producing electric energy and synthesis gas from a coal fuel gasified in oxygen and then in a preferred application, liquefied is used to remove impurities from the cooled mass stream 11-23 of the contaminated carbon monoxide (CO) produced according to the invention in the coal fuel gasification and production of electric energy sub-process 11-10. The process II-30 for purification of the gas which is, according to the invention, a carbon monoxide (CO), usually contaminated, is carried out by means of a technological installation known in the art, which includes a number of technological devices connected to each other in a manner allowing the gas to be purified and preferably comprises a filter, preferably in the form of a cyclone device 11-32, a gas water scrubber 11-34, a waste water treatment plant 11-36, a heat exchanger II-40, into which a mass stream I 1-39 of polluted carbon monoxide from sub process II-20 is fed, a heat exchanger II-40a, to which a hydrogen mass stream III-10d is fed from the sub-process H-20, a condenser 11-42 and an activated carbon bed 11-44. The gas purification sub-process 11-30, and in particular the installation for carrying out this sub process, also comprises a device for removal of hydrogen sulphide (ThS) and carbon dioxide (CO2) from the mass stream 11-23 of the contaminated carbon monoxide (CO).

In general, the sub-process 11-30 for purification of the gas generated in the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen is according to the invention carried out in a manner known in the art, in particular similar to that shown in fig. 1 a gas purification sub-process 1-30 of the coal fuel liquefaction process (UPW) 1-00, for example, according to US2008/0103220 patent in its preamble part concerning the description of the known state of the art for liquefying coal fuel. The cooled mass stream 11-23 of contaminated carbon monoxide at a temperature, preferably 650°C and a pressure preferably of 2.5 MPa is directed to a cyclone filter (cyclone) 11-32 for removal of ash 11-33 and other impurities from the mass stream of contaminated carbon monoxide (CO). Next, the mass stream of contaminated carbon monoxide is directed to the known water scrubber 11-34 of the gas to which water 8 is supplied. The water scrubber II-34 removes impurities from the cooled mass stream II-23 of contaminated carbon monoxide and discharges them together with the mass stream II-34a of waste water. The mass stream II-34a of waste water is directed to sewage treatment plant 11-36 using conventional methods of waste water treatment, whereas the purified carbon monoxide mass stream 11-39 at a temperature, preferably 550 ^° C and a pressure 2.4 MPa is directed to the heat exchanger 11-40, in which a medium pressure steam 4 is generated, the mass stream of which can be used alternatively in another part of the process (UPW II-OO) for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen and supplied it respectively.

The carbon monoxide mass stream H-41 cooled in the heat exchanger H-40 having a temperature preferably 360 ^° C and a pressure preferably 2.3 MPa is directed from the heat exchanger 11-40 to the condenser 11-42 where water condensed from the cooled mass stream 11-41 of carbon monoxide forms a mass stream of condensation water 8. The mass stream of the condensation water 8 may be directed to the gas scmbber 11-34 in the gas purification sub process. The carbon monoxide mass stream 11-43 produced in the condenser 11-42 at a temperature of preferably 340 ^° C and a pressure preferably 2.3 MPa after leaving the condenser 11-42 is fed to the activated carbon bed 11-44. In the activated carbon bed 11-44 a mercury which is an impurity is removed from the carbon monoxide mass stream 11-43. The mass stream 11-43 of purified carbon monoxide is directed to the known Rectisol 11-46 process, in which the removal of hydrogen sulphide (H S) and residual carbon dioxide (CO2) is carried out in the known manner from the mass stream 11-43 of purified carbon monoxide (CO). In the Rectisol 11-46 process the inserted mass stream of a gas in the form of carbon monoxide is separated into the first carbon monoxide mass stream II-46a, containing hydrogen sulphide and carbon dioxide, the second mass stream II-46b containing residual amounts of carbon dioxide and the third mass stream 11-45 of pure carbon monoxide.

The first carbon monoxide mass stream II-46a is directed to the Claus process H-48, in which sulphur II-48a is removed in a known manner from the gaseous hydrogen sulphide which is a component of the second carbon monoxide mass stream II-46a. The starting mass stream II-48b of a carbon monoxide after the Claus process is directed to the next step of the carbon monoxide purification process, which is the known SCOT process II-50, in which carbon monoxide is further purified to form a purified mass stream H-SOa of carbon monoxide at a pressure about 2.2 MPa, which is then mixed with a mass stream 11-45 of pure carbon monoxide, coming from the step of Rectisol process, having a temperature in the range of 335°C to 345°C, preferably 340°C and a pressure within range of 2.2 MPa to form a common mass stream II-45a of a pure carbon monoxide having a temperature in the range of 325°C to 335°C, preferably 330°C and a pressure in the range from 2.19 MPa to 2.21MPa, preferably 2.2 MPa, being the first component of the synthesis gas which flows out from the gas purification sub-process H-30 and then flows into the synthesis gas production sub process 11-40, in particular flowing out by an appropriate discharge line from the technological installation of the gas purification sub-process H-30 and flowing through the appropriate supplying line into the technological installation of the synthesis gas production sub-process 11-40. The second mass stream II-46b of the residual amount of carbon dioxide may be preferably further mixed during this process with glyceryl triethylene (TEG) in the dehydration process II-54, in which water is removed from the residual carbon dioxide mass stream II-46b and may be used anywhere in the coal fuel gasification and electric energy production sub-process 11-10. The above-described stages of gas purification sub-process II- 30, i.e. Rectisol process II-46, Claus process II-48, SCOT process 11-50 and dehydration process (TEG) II-54 are commonly known and used respectively for the removal of sulphur, carbon dioxide and other pollutants in a coal fuel liquefaction process.

From the comparison of the gas purification sub-process 11-30 of the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen according to the invention and in a preferred application preferably subsequently liquefied, with gas purification sub-process 1-30 in the known coal fuel liquefaction process (UPW) I- 00 according to fig. 1 describing the prior art the following differences should be highlighted:

In the technological line of the gas purification sub-process II-30 (see fig. 2) of the process (UPW)-II-O for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, presented in the example of the invention and with reference to the solution according to the invention, the acidity changing reactor for a gas is not used, in contrast to the one used in known technological installation of the known gas purification sub-process 1-30, because according to the invention, in the gas purification sub-process II-30 only the mass stream of carbon monoxide (CO) is subjected to purification, which is produced in addition to electric energy in the coal fuel gasification sub-process 11-10 according to the invention as the only and the main gaseous product obtained in this sub-process, and at the same time it constitutes the first component of the synthesis gas produced in accordance with the method of the invention.

With reference to the solution according to the invention, in the technological line of the gas purification sub-process 11-30 (fig. 2) of the process (UPW) II-O for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, in the Rectisol process 11-46, the carbon monoxide mass stream II-46a contaminated with hydrogen sulphide in subsequent stages, i.e. in Claus process 11-48, followed by SCOT process 11-50 obtains the state of the pure carbon monoxide II-50a, which is mixed with the pure carbon monoxide mass stream 11-45 to form the common carbon monoxide mass stream II-45a, which flows out of the gas purification sub-process 11-30, in particular from the technological installation of the sub-process 11-30 by a suitable discharge duct, and is then directed and fed into the production of synthesis gas sub-process 11-40, in particular to the technological installation of the sub-process 11-40 by a suitable supply duct.

Referring to the solution according to the invention, in the technological line of a preferred embodiment of the gas purification sub-process II-30 (fig. 2) of the process (UPW) II-O for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, in the stage known as the Rectisol process II-46, the mass stream II-46b of residual carbon dioxide which does not exceed 0.1 % of a pure carbon monoxide mass stream II-45a is mixed with triethylene glycol (TEG) in the dehydration process 11-54, and then the residual carbon dioxide mass stream 11-57 is released into the environment. In the embodiment of the invention, in the technological line of the gas purification sub-process 11-30 (fig. 2), an additional heat exchanger II-40a is provided to cool the hydrogen mass stream III-10d supplied and discharged from the thermal energy recovery sub-process II-20, and particularly from the second heat exchanger II-22a, to a temperature in the range of 335°C to 345°C, preferably 340°C at a pressure in the range from 2.19 MPa to 2.21 MPa, preferably 2.2 MPa attaining thermodynamic parameters of the hydrogen mass stream III-10e. A water mass stream 2 from the water reservoir (ZW) is supplied and flows into the heat exchanger II-40a, where it is converted into a medium pressure mass stream 4 using the heat absorbed from the hydrogen mass stream.

According to the invention, in the preferred embodiment, the pure carbon monoxide mass stream II-45a having the temperature, preferably 330°C and the pressure, preferably 2,2 MPa flows out from the gas purification sub-process II-30 and it is directed to the synthesis gas production sub-process 11-40 to form the first component of the synthesis gas.

At the same time, from the high-temperature electrolysis sub-process III-00, in particular from technological installation of this sub-process IH-00, via conduits connections system, the hydrogen (¾) mass stream IH-10 flows out, being the second component of the synthesis gas, and having a temperature in the range from 850°C to 950°C, preferably 900°C and a pressure in the range from 2.9 MPa to 3.1 MPa, preferably 3 MPa, which hydrogen mass stream flows into the compressor III-14 where it is compressed to a pressure from 3.4 to 3.6 MPa, preferably 3.5 MPa at a temperature 900°C to form the hydrogen mass stream III- 10a, which stream is then directed via suitable conduit and flows into the second heat exchanger H-22a of the technological installation of the thermal energy recovery sub-process

II-20 and after leaving it, i.e. at its output, an output hydrogen mass stream Ill-lOd is produced having a temperature in the range from 645°C do 655°C, preferably 650°C and a pressure in the range from 2.45 MPa to 2.55 MPa, preferably 2.5 MPa, which is then directed via suitable conduit and flows into the above mentioned heat exchanger II-40a, that is provided in the installation of the gas purification sub-process 11-30, in which heat exchanger the output hydrogen mass stream III-10e is produced at an outlet of the heat exchanger H-40a having a temperature in the range from 335°C to 345°C, preferably 340°C and a pressure in the range from 2.19 MPa to 2.21 MPa, preferably 2.2 MPa, which as the second component of the synthesis gas is then directed via appropriate conduit connection and flows into synthesis gas production sub-process 11-40, in particular to the technological installation of the sub process H-40.

The process (UPW) H-0 for producing electric power and synthesis gas from a coal fuel gasified in an oxygen according to the invention comprises high-temperature electrolysis sub-process III-00, which is carried out in the technological installation of the high- temperature electrolysis sub-process III-00, in which in the electrolysis process i.e. water splitting process of a supplied high-temperature steam, in the form of the high-temperature steam mass stream 6b, in the process of its splitting (decomposition) into an oxygen and a hydrogen, apart from an oxygen (O ₂ ) in the form of oxygen mass stream HI-8 the hydrogen (¾) is also produced in the form of hydrogen mass stream III-IO, being the second component of the synthesis gas (CO+2H ₂ ), which the high-temperature electrolysis sub process III-00 comprises steps described below, wherein the high-temperature electrolysis sub-process HI-00 is carried out in the technological installation comprising one or more nuclear reactor III-2, preferably a high-temperature helium cooled IV-Generation nuclear reactor HI-2, the heat exchanger III-ll connected to it via conduit system in the manner allowing fluid flow, preferably helium, which is connected to a subsequent heat exchanger HI-12a and to additional heat exchangers HI-13 and III-13a forming together with the heat exchanger III-ll a closed circulation circuit of helium in the form of helium mass streams 1,1a, lb, lc, a steam turbine 7/7-5, supplied with the steam 6 outgoing from heat exchangers

III-12a and III-13 in the form of high-pressure steam mass streams 6c, 6d, 6f and 6e, respectively, an electric energy generator G4 coupled to said steam turbine, a set of high- temperature electrolysers IH-4, comprising at least one or more high-temperature electrolysers HI-4, preferably solid-oxides electrolysers, a compressor III-12 compressing an oxygen mass stream and a compressor HI-14 compressing a hydrogen mass stream, which both the mass streams exit from said high-temperature electrolysers IH-4, wherein the oxygen mass stream IH-8 flowing into the compressor HI-12 is additionally divided into two mass streams, preferably each having equal value, the oxygen mass stream IH-a and the oxygen mass stream Ill-b, wherein one of them, i.e. the oxygen mass stream HI-8a is directed to the coal fuel gasification sub-process 11-10, namely to the coal fuel gasifier H-16 via the check valve HI-5, while the second oxygen mass stream HI-8b can be directed as a final product to commercial consumers or in the preferred application of the method and the system according to the invention it can be directed and used in the methane oxidation process for producing synthesis gas or, alternatively, to the installation of the thermal energy recovery and electric energy production sub-process for supplying gas turbine 11-92.

The high-temperature IV-Generation nuclear reactor IH-2 is cooled in the known manner in the closed circulation circuit by means of the helium mass stream 1, which helium heats up to a temperature 1060°C, wherein the helium mass stream 1, after exiting said reactor is directed to the heat exchanger HI-11. Two water mass streams 2a and 2b supplied from the water tank (ZW) also flow to the heat exchanger HI-11 to cool the helium mass stream 1 heated in the core of the nuclear reactor, each of said water mass streams having separate heat exchanging system. Then, two separate steam mass streams are generated in the heat exchanger III-ll as a result of heat exchange between a hot helium mass stream 1 and said cold water mass streams 2a and 2b, respectively, the high-pressure steam mass stream 6a having a temperature of 900°C and a pressure of 30 MPa and the high-temperature steam mass stream 6b having a temperature of 900°C and a pressure of 3 MPa. The high- temperature steam mass stream 6b is directed to the high-temperature electrolysers set HI-4, where the oxygen mass stream III-8 and the hydrogen mass stream HI-10 are generated in the high-temperature electrolysis process. The high-pressure steam mass stream 6a having a pressure of 30 MPa and temperature of 900°C flows into a subsequent heat exchanger III-12a connected to the installation of the high-temperature electrolysis sub-process III-00, where said high-pressure steam mass stream is cooled to a temperature of 630°C at a pressure of 30 MPa, to form steam mass stream 6c. The water mass stream 2 from the water tank (ZW) flows into this said heat exchanger III-12a and undergoes a phase transition and in the form of a steam exits from this heat exchanger HI-12a to form a high-pressure steam mass stream 6d having a temperature of 620°C and a pressure of 30 MPa, which said steam mass stream 6d is further combined with the above mentioned high-pressure steam mass stream 6c to form together the common high-pressure steam mass stream 6f having a pressure of 30 MPa and a temperature of 620°C. The helium mass stream 1 having a temperature 1060°C and a pressure 3 MPa flows out from the core of the nuclear reactor. In the helium circulation closed-circuit included in the installation of the high-temperature electrolysis sub-process III-00, consisting of helium mass streams 1, la, lb, lc, also additional heat exchangers III-13 and HI-13a are provided which are connected in helium closed cooling circuit of the nuclear reactor core III- 2. The helium stream 1 having temperature of 1060°C and pressure of 3 MPa flowing out from the core of the nuclear reactor III-2 flows into the heat exchanger III-ll, where it is cooled to a temperature of 910°C at a pressure of 3 MPa to create helium mass stream la which then flows into the additional heat exchanger III-13, experiencing a further cooling to a temperature of 630°C at a pressure of 3 MPa and further flowing out of this heat exchanger III-13 forms helium mass stream lb. At the same time, the water mass stream 2 flowing from the water reservoir (ZW) flows into the additional heat exchanger III-13 and cools the helium mass stream la. The water mass stream 2 in the additional heat exchanger III-13 due to the heat transfer from the cooled helium mass stream la undergoes a phase transformation and in the form of a steam 6e exits from the additional heat exchanger HI-13 to form a high-pressure steam mass stream 6e having a temperature of 620 ^° C and a pressure of 30 MPa, which is then supplied to the above mentioned high-pressure steam mass stream 6f having a temperature 620 ^° C and a pressure 30 MPa. The helium mass stream lb flowing out from the additional heat exchanger III-13 flows then into the additional heat exchanger HI-13a where it is cooled to a temperature of 340 ^° C at a pressure of 3 MPa to form a helium mass stream lc, which then, after leaving the said heat exchanger IH-13a, in the helium closed-circuit 1, la, lb, lc flows again into the core of the nuclear reactor III-2. The water mass stream 2 coming out from the water reservoir (ZW) is supplied and flows into the heat exchanger III-13a where it receives the heat flux from the cooled helium, experiencing a phase transition and in the form of a steam 4 flowing out from the heat exchanger IH-14 forms a medium pressure steam mass stream 4 having a temperature 330°C and a pressure 7.5 MPa. Said steam mass streams 6f and 6e after being combined together one with each other form a common high-pressure steam mass stream 6 having a temperature 620 ^° C and a pressure 30 MPa, which is further directed in the installation of the sub-process HI-00 and flowing into the steam turbine III-3, which turbine is a part of the installation of the sub-process HI-00, and is connected to and drives the electric power generator G4 producing the electric current Ill-b for supplying a high- temperature electrolysers set III-4, while the medium pressure steam mass stream 4 flowing out of the steam turbine HI-3 and out of the said additional heat exchanger III-13a can be used anywhere in the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen according to the invention. Additionally, to the high- temperature electrolysers set III-4 in the embodiment of the invention, an electric current II- 92a and electric current II-96b can be supplied, which can be advantageously, in the embodiment variant, respectively generated by electric power generators G2 and G3, e.g. according to the embodiment of the invention in the thermal energy recovery and electric energy production sub-process 11-90. The installation of the high-temperature electrolysis sub-process III-00 is provided with the compressor III-12 which is supplied with the oxygen mass stream III-8 leaving the high-temperature electrolysers III-4 having a temperature in the range of from 850°C to 950°C, preferably about 900°C and a pressure in the range from 2.9 MPa to 3.1 MPa, preferably 3.0, MPa and compresses the said oxygen mass stream to form the oxygen mass stream III-8a having a pressure in the range from 3.4 to 3.6 MPa, preferably 3.5 MPa and a temperature in the range from 890°C to 910°C, preferably 900°C and via the previously mentioned control check valve HI-5 regulating the value of the oxygen mass stream feeds the oxygen mass stream IH-8a to supply the said coal fuel flow gasifier 11-16 with the oxygen in the sub-process H-10 for coal fuel gasification and electric energy production in the manner described above. At the same time, from the compressor HI-12, flows out the oxygen mass stream III-8b having a value that is equal to a half of the value of the total oxygen mass stream HI-8 produced in the high-temperature electrolyser IH-4 and having the same thermodynamic parameters as the said oxygen mass stream III-8a. Additionally, the installation of the high-temperature electrolysis sub-process III-00 comprises a compressor IH-14, which compresses the hydrogen mass stream III-10 coming out from high-temperature electrolysers III-4 of the high-temperature electrolysis sub-process HI-00 having a temperature in the range from 850°C to 950°C, preferably about 900 ^° C and a pressure in the range from 2.9 MPa to 3.1 MPa, preferably 3 MPa to form a hydrogen mass stream III-10a with a pressure from 3.4 to 3.6 MPa, preferably 3.5 MPa and a temperature from 890°C to 910°C, preferably 900°C, which said stream is then directed and supplies the heat exchanger II-22a, connected in the installation of the thermal energy recovery sub process H-20 , in which the said stream is cooled and, wherein at the outlet of this heat exchanger H-22a, a hydrogen mass stream HI-1 Od is produced having a temperature in the range from 645°C to 655°C, preferably 650°C and a pressure in the range from 2.45 MPa to 2.55 MPa, preferably 2.5 MPa, which is then directed and flows into the heat exchanger II- 40a, included in the installation of the gas purification sub-process 11-30, in which it is further cooled and the hydrogen mass stream IH-lOe is produced having a temperature in the range from 335 ^° C to 345 ^° C, preferably 340 ^° C and a pressure in the range from 2.19 to 2.21 MPa, preferably 2.2 MPa, wherein the said hydrogen mass stream Ill-lOe flows into the technological installation of the synthesis gas production sub-process II-40, in particular it flows to the control valve IH-lOb, being a part of the said technological installation of the synthesis gas production sub-process and regulating the value of the hydrogen mass stream, while the adjustable hydrogen mass stream III-l Og formed at the outlet of this said control valve III-10b is then directed to the flowmeter III-l 0c, which measures the hydrogen mass stream value, from which the outgoing hydrogen mass stream III-IO g, as the second component of synthesis gas is finally supplied to the mixing converter 11-69 in the synthesis gas production sub-process II-40.

Both the above mentioned mass streams of synthesis gas components, that are the first (CO) and the second (¾) components, obtained in the above-described sub-processes II- 10, II-20, 11-30 and III-OO, i.e. the pure carbon monoxide (CO) mass stream II-45a produced in the coal fuel gasifier H-16 in the form of a mass stream of contaminated carbon monoxide, constituting the first component of the synthesis gas flowing out from the gas purification sub-process I 1-30 and the hydrogen mass stream Ill-lOe (Eh), also flowing out from the gas purification sub-process 11-30 and precisely from the heat exchanger H-40a, that said hydrogel mass stream is produced in the high-temperature electrolyser III-4, and that constitutes the second component of the synthesis gas, flows out from the gas purification sub-process 11-30 and flows into the synthesis gas production sub-process 11-40 and via said control check valves 11-45 and IH-lOb, connected upstream the entrance of the mixing converter 11-69, for regulating the mass streams values, respectively, the control check valve H-45b for controlling the carbon monoxide mass stream and the control check valve III-l 0b for controlling the hydrogen mass stream, and then via the mass stream flowmeters connected to them, that is respectively, the carbon monoxide mass stream flowmeter H-45c and the hydrogen mass stream flowmeter III-lOc, both the said streams flow into the mixing converter 11-69, in which converter after mixing the said two components of the synthesis gas, i.e. the carbon monoxide with the hydrogen in the molar ratio ncomm ~ 1 :2.12 a synthesis gas is produced having a temperature 330°C and a pressure 2.2 MPa.

The installation of the mixing converter H-69 includes suitable conduits, namely the conduit for discharging the produced synthesis gas mass stream 11-47, connected at the outlet of the said mixing converter as well as conduits exiting from the installation of the gas purification sub-process 11-30 for supplying the pure carbon monoxide mass stream H-45a and the hydrogen mass stream IH-lOe and the said installation includes also the said control check valve II-45b for controlling the carbon monoxide mass stream and the control check valve Ill-lOb of the hydrogen mass stream, connected upstream the inlet of the mixing converter 11-69, respectively, and connected to them, respectively, the carbon monoxide mass stream flowmeter II-45c and the hydrogen mass stream flowmeter III-10c and the converter II-ps2 which converts feedback signals III-lOs and H-45s, preferably electronic, relating to the values of the hydrogen mass stream and the carbon monoxide mass stream, supplied from the flowmeters III-lOc and II-45c, respectively, for the hydrogen mass stream and the carbon monoxide mass stream into the actuating control signals III-lOps and II-45ps, preferably electric, that are then directed to the control check valves, i.e. the said hydrogen mass stream control check valve III-10b and the said carbon monoxide mass stream valve II-45b.

According to the preferred embodiment of the invention, for example shown in fig. 2, to meet the requirement of achieving a desired molar ratio of carbon monoxide (CO) to hydrogen (¾) in the synthesis gas in the mixing converter 11-69 in the produced exiting synthesis gas mass stream P-47, for example, preferably for use in the Fischer-Tropsch process II-60, in accordance with the embodiment of the invention, in the installation of the synthesis gas production sub-process II-40, preferably, two negative feedback systems are used for transmitting the signal II-45s, preferably an electronic, from the flowmeter II-45c included in the carbon monoxide supply conduits, which said signal relates to the measured current value of the mass stream II-45d of the carbon monoxide, and the signal III-lOs, preferably electronic, from the flowmeter III-10c included in the hydrogen supply conduits, which said signal relates to the measured current value of the mass stream III-10g of the hydrogen, to the feedback control signals converter 77-ps2, preferably electronic, which converts them according to the pre-set condition of the desired molar ratio nco:nH2 ~ 1 :2.12 respectively into the control actuating signals, preferably electric, i.e. the actuating electrical signal II-45ps for the carbon monoxide and the electrical actuating signal III-10ps for the hydrogen, to control, respectively, the control check valve II-45b adjusting and regulating the carbon monoxide mass stream value and the control check valve IH-lOb adjusting and regulating the hydrogen mass stream value, which said control check valves are connected upstream of the mixing converter 11-69, looking in the direction of the gas flow. In the mixing converter 77-69, both regulated mass streams, i.e. the regulated hydrogen mass stream IH-lOg and the regulated carbon monoxide mass stream II-45d, are mixed together to form, at the exit of the mixing converter, the synthesis gas with a pre-determined molar ratio ncoinm ~ 1 :2.12 and determined thermodynamic parameters i.e. the temperature of 340°C and the pressure of 2.20 MPa in the form of the exiting or final synthesis gas mass stream 11-47.

The output final synthesis gas mass stream 11-47 produced in the mixing converter 11-69, hereinafter referred to as "syngas", according to the preferred variant of the embodiment of the invention and in the preferred application of the method and the system (UPW) 11-00 for producing electric energy and a synthesis gas from a coal fuel gasified in an oxygen according to the invention, flows out of the synthesis gas production sub-process II- 40 and can flow or flows, preferably via a suitable conduit connection, into the technological line of the Fischer-Tropsch process 11-60, for which it is a substrate necessary for the production of synthetic liquid fuels as shown in the embodiment in fig. 2 and fig. 3.

Example of the application

In the process (UPW) 11-00 for producing electric energy and a synthesis gas from a coal fuel gasified in an oxygen and further in the preferred application of the method and the system, or alternatively in the advantageous continuation of the process and system (UPW) II-OO according to the invention, liquefied in the Fischer-Tropsch sub-process 11-60 for producing synthetic liquid fuels, in the part starting from the exit of the synthesis gas mass stream 11-47 from the synthesis gas production sub-process 11-40 and ending at the exit of the final gas mass stream II-91 from the Fisher-Tropsch sub-process 11-60, can be preferably carried out in any of the known methods and processes, for example similarly as the Fischer- Tropsch sub-process 1-60 of the coal fuel liquefaction process (UPW) 1-00 or, for example, in accordance of the US2008/0103220 patent in its initial and preamble part concerning the description of the known prior art of a coal fuel liquefaction.

Thus, the synthesis gas mass stream 11-47 from the process (UPW) 11-00, in particular from the synthesis gas production sub-process II-40 is fed and supplies the Fischer- Tropsch process 11-60, in which the synthesis gas mass stream 11-47 is converted into liquid synthetic fuel. The installation of the Fischer-Tropsch process, in advantageous embodiment can comprise first Fischer-Tropsch reactor 11-62, first heat exchanger 1-64, first separation unit 1-66, a compressor 11-68, second Fischer-Tropsch reactor 1-72, second heat exchanger I- 74, second separation unit 1-76, a hydrocracker 1-70, a hydrogen separation membrane 1-78, second compressor II-80, a cistern 11-82 and a distillation column 1-84. In the Fischer- Tropsch sub-process II-60 the syngas mass stream 11-47 is directed to feed the first Fischer- Tropsch reactor 11-62, where the hydrogen and the carbon monoxide in the syngas mass stream 1-47 are converted into liquid fuel, in particular into the first hydrocarbon mass stream 11-63 in the catalytic reaction represented by equation (1):

(2n + 1 )H ₂ + 7iCO ® c„H _2n+2 + nH ₂ 0 where n is a natural number and may range from 1 to about 42, although it may be greater than 42. For example for light hydrocarbons n may be in the range of 1 to about 7, for intermediate hydrocarbons n may be in the range of about 8 to about 13, and for heavy hydrocarbons n can take values above 14.

The first hydrocarbons mass stream II-63 comprises both a liquid fuel as well as a gas from the first Fischer Tropsch reactor 11-62, which are cooled in the first heat exchanger II-64. The water mass stream 2 from the water tank (ZW) supplies the first heat exchanger II- 64 where it absorbs heat from the first hydrocarbons mass stream II-63 while cooling it to producing the medium pressure steam mass stream 4, which is purified in another process. The cooled first hydrocarbon mass stream 11-63 feeds the first separation unit 11-66, where different components from the first hydrocarbons mass stream 1-63 are separated from each other. The mass stream 11-67 of remaining syngas separated from the said hydrocarbon mass stream 1-63 as a result of separation in the first separation unit 11-66 and purified feeds the second Fischer-Tropsch reactor 11-72. The liquid fuel mass stream separated from the hydrocarbons mass stream 1-63 is divided in the first separation unit 11-66 into two hydrocarbon mass streams: the first light hydrocarbons mass stream II-66a containing intermediate distillates and light hydrocarbons and the first heavy hydrocarbons mass stream II-66b containing heavy hydrocarbons. The first separation unit 11-66 also removes water 8, usually condensed water, from the first hydrocarbons mass stream 11-63 and purifies the water mass stream 8 from other products, in particular from impurities. The syngas mass stream II- 67 from the first separation unit 11-66 is compressed in the compressor 11-68 and feeds the second Fischer-Tropsch reactor 11-72, where the syngas mass stream 11-67 is converted in the catalytic reaction into liquid fuel, according to catalytic reaction (1). The second hydrocarbon mass stream I 1-73 produced at the outlet from the second Fischer-Tropsch reactor 11-72 is cooled in the second heat exchanger 11-74 and then it is directed to the second separation unit 11-76, whereas to the second heat exchanger 11-74 the water mass stream 2 from the tank (ZW) is supplied to feed it, which said water absorbs a heat from the second hydrocarbons mass stream 11-73 to produce medium pressure steam mass stream 4, which is purified to be used in another sub-processes, for example it can be fed and used in the process for producing electric energy and synthesis gas from a coal fuel. The second separation unit 77-76 separates and divides the second hydrocarbons mass stream 11-73 into its various components. The water 8 separated and branched out from the second hydrocarbons mass stream 77- 73 is purified in the second separation unit 1-76 and can be used anywhere. The liquid fuel separated from the second hydrocarbons mass stream II-73 is separated or divided into two hydrocarbons mass streams. The first stream from the second light hydrocarbons mass stream II-76a containing intermediate distillates and light hydrocarbons and the second stream from the second heavy hydrocarbons mass stream II-66b containing heavy hydrocarbons. The final gases 77-77 separated from the second hydrocarbons mass stream 11-73 in the second separation unit 11-76 are directed to the hydrogen separating membrane 11-78, from which the hydrogen (¾) mass stream 11-79 obtained from the final gases is directed to the compressor 1-80. The heavy hydrocarbons produced in the Fischer-Tropsch sub-process 1-60 are converted in the hydrocracker 11-70 into light hydrocarbons or liquid fuels. The first heavy hydrocarbons mass stream II-66b and the second heavy hydrocarbons mass stream II-76b produced in the Fischer-Tropsch reactors are mixed with each other forming the hydrocarbons mass stream II-66c feeding the hydrocracker 11-70. The heavy hydrocarbons mass stream 77- 85 from the distillation column 11-84 also feeds the hydrocracker 11-70. The hydrogen 11-79 separated from the final gases 77-77 by the hydrogen-separation membrane 11-70 is compressed by means of the compressor 11-80 before it being directed to and feeding the hydrocracker II-70 to facilitate the hydrocracking process of light hydrocarbons or liquid fuels forming hydrocarbons mass stream 77-77 flowing out from the hydrocracker 11-70. Said hydrocarbons mass stream 77-77 is combined with the second light hydrocarbons mass stream

I-76a and with the first light hydrocarbons mass stream II-66a and then these said streams are mixed in the cistern II-82 to form the light hydrocarbons mass stream II-83. The light hydrocarbons mass stream 11-83 feeds the distillation column 11-84. Inside the distillation column 11-84, the products of light hydrocarbons 11-83 from the Fischer-Tropsch sub-process

II-60 are distilled into heavy gasoline 11-86 and diesel oils 11-87. The heavy hydrocarbons mass stream 11-85 produced in the distillation column 11-84 is removed from the distillation column 11-84 and directed to the hydrocracker 11-70. The pure gases II-88 from the distillation column 11-84 can be combined with the final gas 77-77 and then feed the hydrogen separation membrane 11-78 to separate hydrogen from the pure gases 11-88. The final gas 77- 91 flowing out of the hydrogen separating membrane 11-78 from pure gases 11-88 flows out from the Fischer-Tropsch sub-process and enters into the thermal energy recovery and electric energy production sub-process 11-90. According to the embodiment of the application of the method and the system in line with the invention, in a preferred variant of implementation, in the technological line of the Fischer-Tropsch process 11-60 (as illustrated for example in fig. 2), to which the final synthesis gas mass stream H-47, produced according to the invention, is fed from the cooperating technological line of the process (UPW) II-OO for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, and precisely from the mixing converter 11-69, which in preferred application is further liquefied, the thermal energy recovery and electric energy producing sub-process 11-90 from the outlet gas mass stream 11-91 flowing out from the Fischer-Tropsch process H-60 is provided or is additionally included in the Fischer- Tropsch process H-60. The outlet gas mass stream 11-91 flowing out from the installation of the Fischer-Tropsch process 11-60 and flowing into the installation of the thermal energy recovery and electric power production sub-process 11-90 feeds the gas turbine 11-92, to which preferably, in the variant of the invention, the oxygen mass stream III-8b from the high-temperature electrolysis sub-process III-OO of the process (UPW) II-OO for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, can be supplied, wherein in the oxygen mass stream IH-8b a combustion of the final gas mass stream 11-91 is carried out and the exhaust gas mass stream H-93 is formed to power the gas turbine 11-92 coupled to the electric energy generator G2, which generates electric current II-92a. Exhaust gas mass stream H-93 outgoing from the gas turbine 11-92 is directed to the generator 11-94 for heat recovery from a steam, in which the water mass stream 2, supplied from the water tank ( ZW) is heated and the medium pressure steam mass stream 4 is heated, which streams flow into the generator 11-94 for heat recovery from a steam. In the generator 11-94 for heat recovery from a steam, the high-pressure steam 11-95 is produced which is produced in the generator 11-94 for heat recovery from a steam, which is fed and supply the condensation steam turbine 11-96, coupled with the electric energy generator G3 producing electric current II-96b. The water 2 obtained in the condensation steam turbine H-96 is directed to the water tank (ZW). The exhaust gas mass stream can be further purified or released to the environment.

In the embodiment of the method and the system according to the invention, according to preferred or alternative variant of an implementation, in the technological line of the thermal energy recovery and electric energy production sub-process H-90 (fig.2), in the gas turbine 11-92 supplied with the final gas mass stream H-91 from the Fischer-Tropsch sub process H-60, the final gas mass stream II-91 is combusted in the oxygen mass stream III-8b produced, as presented above, in the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel in the sub-process of high-temperature electrolysis III-00 according to the invention.

Example of the application

Below, one more preferred variant or embodiment of the application or the use of the process (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen according to the invention is presented, which can be used in the process and installation for methane oxidation, for example the methane obtained from demethanization of hard coal mines, for example in the manner presented below. Due to the electrolysis reaction of high-temperature water in sub-process III-00

2H ₂ 0 => 2H ₂ + 0 ₂ (3). the gasification reaction of a carbon into a carbon monoxide in the sub-process 11-10 and the synthesis reaction of the synthesis gas into methanol, in the process Fischer- Tropsch the production of the total oxygen mass stream III-8 i.e. the oxygen resource produced from the high-temperature electrolysis sub-process III-00 of the process for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen, it is two times greater than required to carry out a full synthesis of the synthesis gas into the methanol.

Therefore, a half of the oxygen mass stream HI-8 obtained from the high-temperature electrolysis III-00 remains for further use, namely the oxygen mass stream III-8b. This fact allows to further develop the process for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen (UPW) II-OO and, in the preferred example of application, liquefied, as illustrated in fig. 2, by adding the methane oxidation sub-process IV-00. The modified process for producing electric energy from a coal fuel gasified in an oxygen according to the invention and, in the preferred application of the invention, then liquefied, is marked with a symbol (ZUPW) 11-00 and is illustrated in fig. 3. In general, the oxidation of hydrocarbons occurs according to the reaction

For n=l and m=4 the reaction has the form, where n and m are natural numbers and it is the oxidation reaction of a methane into a synthesis gas (CO+ 2Hi). Methane can be extracted from demethanization process of mines, where now it is mostly released into the atmosphere, which, from the point of view of the protection of the environment is not favorable. However, more and more mines recover methane for commercial purposes, using it mainly for the production of synthesis gas, mainly with the use of steam reforming method.

A method alternative for steam reforming process of methane oxidation into the synthesis gas, is the method of catalytic oxidation of methane (Catalyc Partial Oxidation) CPOx, which is much cheaper and faster. Methane reacts with the oxygen in the presence of a catalyst to form synthesis gas. The reaction occurs in less than 1 ms in a range of pressures from 2.8 to 3.0 MPa preferably 2.9 MPa, which results in a significant reduction in the size and complexity of the design of the reactor. The methane mass stream IV-10 from a demethanization of mines at a pressure in the range of 2.8 to 3.0 MPa preferably 2.9 MPa and a temperature of about 30°C flow into methane oxidation sub-process IV-00. From the modified installation of the process for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen (ZUPW) 11-00, the oxygen mass stream III-8b, produced in the high-temperature electrolysis sub-process 111-00 , in the amount equal to a half of the value of the total oxygen mass stream 111-8 , having a pressure range from 3.4 to 3.6 MPa preferably 3.5 MPa and a temperature of 850°C to 950°C, preferably 900°C comes out from the high-temperature electrolysis sub-process III-00 and flows into the thermal energy recovery and electric energy production sub-process 11-90, where it is cooled in the heat exchanger 11-97 to create the oxygen mass stream III-8c having a temperature in the range from 645°C to 655°C, preferably 650°C and a pressure in the range from 3.1 to 3.2 MPa, preferably 3.15 MPa. The water mass stream 2 from water tank ( ZW) flows into the heat exchanger 11-97 where the high-pressure steam mass stream 6 is generated having a temperature in the range from 610°C to 630°C, preferably 620°C and a pressure in the range from 29.5 to 30.5 MPa, preferably 30 MPa to supply then the generator II-94 for heat recovery from a steam. The oxygen mass stream III-8c flows then into the heat exchanger 77- 99 where it is cooled to create the oxygen mass stream III-8d having a temperature in the range from 335°C to 345°C preferably 340°C and a pressure in the range from 2.8 to 3.0 MPa preferably 2.9 MPa. The water mass stream 2 from the water tank ( ZW) flows into the heat exchanger 11-99 where the medium pressure steam mass stream 4 is generated having a temperature in the range from 320°C to 340°C preferably 330°C and a pressure in the range from 7.4 to 7.6 MPa preferably 7.5 MPa. The medium pressure steam 4 flowing out of the heat exchanger 11-99 can be used anywhere in the modified process for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen and liquefied (ZUPW) 11-00. The oxygen mass stream III-8d flows out of the thermal energy recovery and electric energy production sub-process II-90 and flows into the methane oxidation sub-process IV-00. In the methane oxidation sub-process IV-00 both the methane mass stream IV-10 and the oxygen mass stream III-8d flow into the reactor for catalytic oxidation of methane CPOx, in which the synthesis gas is produced forming the synthesis gas mass stream IV-20 having a temperature in the range from 810°C to 790°C, preferably 800°C and a pressure in the range from 2.8 to 3.0 MPa preferably 2.9 MPa. The synthesis gas mass stream IV-20 flowing out from the reactor CPOx flows into the heat exchanger IV-11 to form when leaving it the synthesis gas mass stream IV-21 having a temperature in the range from 620°C to 640°C, preferably 630°C and a pressure in the range from 2.5 to 2.7 MPa, preferably 2.6 MPa. To the heat exchanger IV-11 flows the water mass stream 2 from water tank (ZW) that receives the heat flux from the cooled synthesis gas mass stream IV-20 undergoing phase transition and in the form of the high-temperature steam 6 having a temperature in the range from 610°C to 630°C, preferably 620°C and a pressure in the range from 29.5 to 30.5 MPa, preferably 30 MPa, flows out from the methane oxidation sub-process IV-00 and then flows into the heat recovery and electric energy production sub-process 11-90 to supply the generator 11-94 for heat recovery from a steam. The generator 11-94 for heat recovery from a steam in the modified process (ZUPW) II-00 for producing electric energy and synthesis gas from a coal fuel, in the preferred use of the invention, is also heated up with the exhaust gases mass stream 11-93 resulting from the combustion of the final gas mass stream 11-91 in an air mass stream 11-19 in the gas turbine 77-92. The synthesis gas mass stream IV- 21 flowing out from the heat exchanger IV-12 to form after flowing out the synthesis gas mass stream IV-22 having a temperature in the range from 330°C to 350°C preferably 340°C and a pressure in the range from 2.1 to 2.3 MPa, preferably 2.2 MPa. To the heat exchanger IV-12 flows the water mass stream 2 from the water tank (ZW) that cools the synthesis gas mass stream IV-21 and in the form of the medium pressure steam 4 having a temperature in the range 320°C to 340°C, preferably 330°C and a pressure in the range from 7.4 to 7.6 MPa, preferably 7.5 MPa, can be used anywhere in the modified process (ZUPW) 11-00 for producing electric energy and synthesis gas from the coal fuel gasified in an oxygen and then liquefied. The synthesis gas mass stream IV-22 flows out from the methane oxidation sub-process IV-00 and flows into the synthesis gas production sub-process 11-40 where it is directed and then flows into the installation of the mixing converter 11-69 to produce the synthesis gas having the desired, above-mentioned molar ratio.

Comparative Examples

For example, the production of synthesis gas in the simulation of the process of liquefaction of a coal fuel (UPW) 1-00 according to the prior art is illustrated in fig. 1, is compared to the simulations of the process (UPW) II-OO for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen and, in a preferred example of the application, liquefied, as illustrated in fig. 2, and according to the modified process (ZUPW) II-OO for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen and liquefied illustrated in fig. 3, is presented in Tab. 1. The simulation was carried out by the software using DELPHI 7 compiler. Tab. 1.

(UPW) 1-00 (UPW) II-OO (ZUPW)

II-OO

The power of the power plant

achieved from the coal fuel [MW _e ]

200 200 200

Coal fuel mass stream 20 71,2 71,2

33 51 102

8

Methane mass stream 6,17 51,02 s

Hydrogen mass stream kg

2,173 12,75 25,5 s

Carbon monoxide mass stream kg 11,19 89,29 178,58 s

Carbon dioxide mass stream kg_ 30,78 0,089 0,091 s Synthesis gas mass stream kg 13,34 102,04 204,08 s

From the above comparison results that using the method (UPW) 11-00 for producing electric energy and synthesis gas from a coal fuel gasified in an oxygen according to the invention, while obtaining the same power of a coal power plant, we can obtain over 7.6 times greater synthesis gas mass stream than in the case of the known technology for producing synthesis gas in the coal fuel liquefaction process (UPW) 1-00 according to prior art, or, for example, in accordance to the US2008/0103220 patent in its preamble part regarding the description of the known prior art of a coal fuel liquefaction, while approximately 3.5 x increase in a coal fuel consumption. Whereas, in the case of the application of the modified process for electric energy and synthesis gas production from a coal fuel gasified in an oxygen (ZUPW) II-OO according to the invention we can get up more than 15 times greater the synthesis gas mass stream.