JP7207523B2 - hydrocarbon combustion system - Google Patents

Description

The present disclosure relates to hydrocarbon combustion systems. This application claims the benefit of priority based on Japanese Patent Application No. 2019-069808 filed on April 1, 2019, the content of which is incorporated herein by reference.

Patent Literature 1 discloses that renewable energy is used to generate electric power, and that the generated electric power is used to generate heat with an electric heater. However, power generation using renewable energy has the problem that the amount of power generation fluctuates depending on the time of day, and the timing of heat demand and supply does not always match.

On the other hand, Patent Document 2 describes generating electric power using renewable energy, using the generated electric power to generate hydrogen by an electrifier, and using the generated hydrogen to generate methane by a methanation reactor. There is disclosure. If the generated methane can be stored and burned as needed, heat demand can be met regardless of the time of day.

JP 2014-31787 A JP 2017-197399 A

However, in Patent Document 2, water is required in order to generate hydrogen by the electrizer. In other words, in Patent Literature 2, it is necessary to supply water to the electrizer as needed when generating hydrogen using renewable energy. Impurities must be removed from this water in advance in order to prevent deterioration in electrifier performance due to deposition of impurities. In addition, when carbon dioxide is supplied from outside the system, carbon dioxide can be recovered from combustion exhaust gas by chemical absorption methods such as amine absorption, physical absorption methods, and membrane separation methods. It takes a lot of energy to separate Therefore, in Patent Document 2, there is a problem that the cost is increased compared to the case of generating heat by the electric heater of Patent Document 1.

SUMMARY OF THE DISCLOSURE The present disclosure seeks to provide a hydrocarbon combustion system capable of reducing costs in producing heat.

In order to solve the above problems, a hydrocarbon combustion system as one aspect of the present disclosure includes an electrolyzer that generates hydrogen using power generated from renewable energy, hydrogen generated by the electrolyzer, and dioxide A hydrocarbon generator that uses carbon to generate hydrocarbons, a hydrocarbon reservoir that stores the hydrocarbons generated by the hydrocarbon generator, and a closed combustion that burns the hydrocarbons extracted from the hydrocarbon reservoir. a separation unit that separates carbon dioxide and water generated by combustion of hydrocarbons, sends carbon dioxide to the hydrocarbon generator and water to the electrolyzer, and heat generated by the hydrocarbon generator to the hydrocarbon reservoir; and
Prepare.
In order to solve the above problems, a hydrocarbon combustion system as another aspect of the present disclosure includes an electrolyzer that generates hydrogen using power generated from renewable energy, and hydrogen generated by the electrolyzer. a hydrocarbon generator for generating hydrocarbons using carbon dioxide; a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator; A separation unit that separates carbon dioxide and water generated by combustion of hydrocarbons, sends carbon dioxide to the hydrocarbon generator and water to the electrolyzer, and a closed combustor. a heat supply for supplying the heat to the hydrocarbon reservoir.

A carbon oxide storage section for storing carbon dioxide delivered from the separation section may be further provided.

A carbon oxide supply control unit for controlling the amount of carbon dioxide circulating through the hydrocarbon generator, the hydrocarbon reservoir, the closed combustor, and the separation unit may be further provided.

A water storage section for storing water delivered from the separation section may be further provided.

A water supply controller for controlling the amount of water circulating through the electrolytic device, the closed combustor, and the separation section may be further provided.

In order to solve the above problems, a hydrocarbon combustion system as another aspect of the present disclosure includes an electrolysis device that uses power generated from renewable energy to generate hydrogen and carbon monoxide, and a hydrocarbon generator for generating hydrocarbons using the hydrogen and carbon monoxide obtained, a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator, and hydrocarbons taken out from the hydrocarbon reservoir and a closed combustor for delivering carbon dioxide and water to the electrolyzer ; and a heat supply for supplying heat produced by the hydrocarbon generator to the hydrocarbon reservoir .
In order to solve the above problems, a hydrocarbon combustion system as another aspect of the present disclosure includes an electrolysis device that uses power generated from renewable energy to generate hydrogen and carbon monoxide, and a hydrocarbon generator for generating hydrocarbons using the hydrogen and carbon monoxide obtained, a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator, and hydrocarbons taken out from the hydrocarbon reservoir and a closed combustor for delivering carbon dioxide and water to the electrolyzer; and a heat supply for supplying the heat generated in the closed combustor to the hydrocarbon reservoir.

A combustion gas reservoir for storing carbon dioxide and water delivered from the closed combustor may be further provided.

It may further include an electrolyzer, a hydrocarbon generator, a hydrocarbon reservoir, and a combustion gas supply controller that controls the amount of carbon dioxide and water circulating through the closed combustor.

A circulation pipe may be further provided for recirculating part of the combustion gas discharged from the downstream side of the closed combustor to the upstream side of the closed combustor.

According to the present disclosure, hydrocarbon combustion systems can reduce costs in producing heat.

FIG. 1 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system according to a first embodiment. FIG. 2 is a block diagram showing a schematic configuration of the control device of the first embodiment. FIG. 3 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system according to the second embodiment. FIG. 4 is a schematic configuration diagram of a hydrocarbon reservoir. FIG. 5 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system according to the third embodiment. FIG. 6 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system in a fourth embodiment. FIG. 7 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system according to the fifth embodiment. FIG. 8 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system in a sixth embodiment. FIG. 9 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system in a seventh embodiment. FIG. 10 is a block diagram showing a schematic configuration of a control device according to the seventh embodiment. FIG. 11 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system in an eighth embodiment. FIG. 12 is a block diagram showing a schematic configuration of the control device of the eighth embodiment.

Embodiments of the present disclosure will be described in detail below with reference to the accompanying drawings. Dimensions, materials, and other specific numerical values shown in the embodiments are merely examples for facilitating understanding, and do not limit the present disclosure unless otherwise specified. In this specification and the drawings, elements having substantially the same functions and configurations are denoted by the same reference numerals, thereby omitting redundant description. Illustrations of elements that are not directly related to the present disclosure are omitted.

[First embodiment]
FIG. 1 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 100 according to the first embodiment. Solid arrows in FIG. 1 indicate the flow of gas or liquid. In FIG. 1, dashed arrows indicate the flow of signals. As shown in FIG. 1, the hydrocarbon combustion system 100 includes a carbon oxide reservoir 102, a water reservoir 104, an electrolyzer 106, a hydrocarbon generator 108, a gas-liquid separator 110, and a hydrocarbon reservoir. 112 , a closed combustor 114 , and a gas-liquid separator (separator) 116 .

Carbon oxide reservoir 102 stores carbon oxide. A predetermined amount of carbon oxide is stored in advance in the carbon oxide reservoir 102 before the hydrocarbon combustion system 100 is operated for the first time. However, the carbon oxide reservoir 102 may be externally supplied with a predetermined amount of carbon oxide when the hydrocarbon combustion system 100 is operated for the first time. In the first embodiment, the carbon oxide reservoir 102 stores carbon dioxide (CO ₂ ) as carbon oxide. However, the present invention is not limited to this, and the carbon oxide reservoir 102 may store carbon monoxide (CO) as the carbon oxide. A first pipe 118 is arranged between the carbon oxide reservoir 102 and the hydrocarbon generator 108 . A first pipe 118 communicates between the carbon oxide reservoir 102 and the hydrocarbon generator 108 . Carbon oxide reservoir 102 supplies carbon oxide (CO ₂ in FIG. 1) to hydrocarbon generator 108 via first pipe 118 .

The water storage unit 104 stores water (liquid water or water vapor: H ₂ O in the first embodiment). A predetermined amount of water is stored in the water reservoir 104 in advance before the hydrocarbon combustion system 100 is operated for the first time. However, the water reservoir 104 may be supplied with a predetermined amount of water from the outside when the hydrocarbon combustion system 100 is operated for the first time. A second pipe 120 is arranged between the water reservoir 104 and the electrolytic device 106 . A second pipe 120 communicates between the water reservoir 104 and the electrolytic device 106 . Water reservoir 104 supplies water (2H ₂ O (4H ₂ O) in FIG. 1) to electrolytic device 106 via second pipe 120 .

As will be described later, in the first embodiment, the hydrocarbon combustion system 100 changes the amount of water supplied from the water reservoir 104 to the electrolyzer 106 according to the elapsed time after starting operation. Specifically, the hydrocarbon combustion system 100 causes the water reservoir 104 to supply the electrolyzer 106 with 4H ₂ O water shown in parentheses in FIG. 1 at the start of operation. Further, the hydrocarbon combustion system 100 supplies 2H ₂ O water shown in FIG.

The electrolyzer 106 is connected to a power generator (not shown) that generates power from renewable energy. Electric power is supplied to the electrolytic device 106 from a power generator (not shown). Further, water (4H ₂ O in FIG. 1) is supplied from the water reservoir 104 to the electrolysis device 106 when the hydrocarbon combustion system 100 starts operating (initial time). The electrolytic device 106 produces hydrogen (4H ₂ in FIG. 1) and oxygen (2O ₂ in FIG. 1) from the supplied electric power and water.

A third pipe 122 is arranged between the electrolyzer 106 and the hydrocarbon generator 108 . A third pipe 122 communicates between the electrolytic device 106 and the hydrocarbon generator 108 . The electrolyzer 106 supplies hydrogen (4H ₂ in FIG. 1) to the hydrocarbon generator 108 via the third pipe 122 .

A fourth pipe 124 is arranged between the electrolyzer 106 and the closed combustor 114 . A fourth pipe 124 communicates between the electrolytic device 106 and the closed combustor 114 . The electrolytic device 106 supplies oxygen (2O ₂ in FIG. 1) to the closed combustor 114 through the fourth pipe 124 .

The hydrocarbon generator 108 converts the supplied hydrogen (4H ₂ in FIG. 1) and carbon oxide (CO ₂ in FIG. 1) into hydrocarbons (CH ₄ in FIG. 1) and water (2H ₂ O). The hydrocarbon generator 108 is, for example, a methanation reactor (Sabatier reactor). In the first embodiment, the hydrocarbon generator 108 produces methane (CH ₄ in FIG. 1) and water vapor (2H ₂ O in FIG. 1). However, without being limited to this, the hydrocarbon generator 108 may generate hydrocarbons (combustible gases) other than methane, such as ethane, propane, and butane.

A fifth pipe 126 is arranged between the hydrocarbon generator 108 and the gas-liquid separator 110 . The fifth pipe 126 allows the hydrocarbon generator 108 and the gas-liquid separator 110 to communicate with each other. The hydrocarbon generator 108 supplies hydrocarbons (methane: CH ₄ in FIG. 1) and water (steam: 2H ₂ O in FIG. 1) to the gas-liquid separation section 110 via the fifth pipe 126 .

In the first embodiment, the fifth pipe 126 is provided with a cooling device (not shown). The cooling device cools hydrocarbons (methane: CH ₄ in FIG. 1) and water (steam: 2H ₂ O in FIG. 1) flowing through the fifth pipe 126 . The chiller cools to a temperature that liquefies water (water vapor) without condensing hydrocarbons (methane). Water vapor becomes liquid water by being cooled by a cooling device.

The gas-liquid separation unit 110 separates the supplied hydrocarbon (methane) and water into gas-liquid separation. A sixth pipe 128 is arranged between the gas-liquid separation section 110 and the hydrocarbon storage section 112 . The sixth pipe 128 allows the gas-liquid separation section 110 and the hydrocarbon storage section 112 to communicate with each other. The gas-liquid separation unit 110 supplies the separated hydrocarbon (CH ₄ in FIG. 1) to the hydrocarbon storage unit 112 via the sixth pipe 128 .

A seventh pipe 130 is arranged between the gas-liquid separator 110 and the electrolytic device 106 . The seventh pipe 130 communicates between the gas-liquid separator 110 and the electrolytic device 106 . The gas-liquid separator 110 supplies (returns) the separated water (2H ₂ O in FIG. 1) to the electrolytic device 106 via the seventh pipe 130 .

The hydrocarbon storage unit 112 stores the supplied hydrocarbon (CH ₄ in FIG. 1). An eighth pipe 132 is arranged between the hydrocarbon reservoir 112 and the closed combustor 114 . Eighth pipe 132 communicates hydrocarbon reservoir 112 with closed combustor 114 . The hydrocarbon reservoir 112 supplies hydrocarbons (CH ₄ in FIG. 1) to the closed combustor 114 via the eighth pipe 132 .

By the way, the amount of power generated by renewable energy fluctuates depending on the time of day. Therefore, when heat is generated by an electric heater, there is a problem that the timing of heat demand and supply do not necessarily match. Therefore, the hydrocarbon combustion system 100 includes a hydrocarbon storage section 112 that stores hydrocarbons generated based on renewable energy.

The hydrocarbon reservoir 112 can store and release (release) hydrocarbons produced from renewable energy. Accordingly, the hydrocarbon storage unit 112 can store the produced hydrocarbons when the heat demand is low and release the stored hydrocarbons when the heat demand is high.

As a result, the hydrocarbon combustion system 100 can supply the hydrocarbons stored in the hydrocarbon reservoir 112 to the closed combustor 114 for combustion at any time and in any amount as needed. Accordingly, the hydrocarbon combustion system 100 can meet heat demands regardless of the time of day. That is, the hydrocarbon combustion system 100 stores hydrocarbons generated based on renewable energy, and supplies the stored hydrocarbons to the closed combustor 114 as needed, thereby adjusting the timing of heat demand and supply. can be matched.

Closed combustor 114 mixes and combusts hydrocarbons (CH ₄ in FIG. 1) and oxygen (2O ₂ in FIG. 1) taken out from hydrocarbon reservoir 112 . The closed combustor 114 is, for example, a radiant tube burner. The closed combustor 114 produces heat by burning a fuel gas (a mixture of hydrocarbons and oxygen). The heat generated in closed combustor 114 is used, for example, for heat treatment. Specifically, the heat produced in the closed combustor 114 is used to heat the workpieces in the furnace.

The closed combustor 114 produces carbon oxide (carbon dioxide: CO ₂ in FIG. 1) and water (water vapor: 2H ₂ O ). A ninth pipe 134 is arranged between the closed combustor 114 and the gas-liquid separator 116 . The ninth pipe 134 communicates between the closed combustor 114 and the gas-liquid separator 116 . The closed combustor 114 supplies carbon oxide (CO ₂ in FIG. 1) and water (2H ₂ O in FIG. 1) to the gas-liquid separator 116 via the ninth pipe 134 .

In the first embodiment, the ninth pipe 134 is provided with a cooling device (not shown). The cooling device cools carbon oxide (carbon dioxide: CO ₂ in FIG. 1) and water (water vapor: 2H ₂ O in FIG. 1) flowing through the ninth pipe 134 . The chiller cools to a temperature that liquefies water (water vapor) without condensing carbon oxide (carbon dioxide). Water vapor becomes liquid water by being cooled by a cooling device.

The gas-liquid separator 116 separates the supplied carbon oxide (carbon dioxide) and water into gas-liquid. That is, the gas-liquid separation unit 116 separates water and carbon oxide (carbon dioxide) produced by combustion of the fuel gas (a mixture of hydrocarbon and oxygen) in the closed combustor 114 . A tenth pipe 136 is arranged between the gas-liquid separator 116 and the carbon oxide reservoir 102 . A tenth pipe 136 communicates between the gas-liquid separator 116 and the carbon oxide reservoir 102 . The gas-liquid separation unit 116 supplies (delivers) the separated carbon oxide (CO ₂ in FIG. 1) to the carbon oxide storage unit 102 via the tenth pipe 136 . The carbon oxide storage unit 102 can store the carbon oxide generated in the closed combustor 114, and supplies the carbon oxide necessary for driving the hydrocarbon generator 108 to the hydrocarbon generator 108 at an arbitrary timing. can do.

An eleventh pipe 138 is arranged between the gas-liquid separator 116 and the water reservoir 104 . The eleventh pipe 138 communicates between the gas-liquid separator 116 and the water reservoir 104 . The gas-liquid separator 116 supplies (delivers) the separated water (2H ₂ O in FIG. 1) to the water reservoir 104 via the eleventh pipe 138 . The water storage unit 104 can store the water (steam) generated in the closed combustor 114, and can supply the water necessary for driving the electrolysis device 106 to the electrolysis device 106 at any timing. .

Thus, the hydrocarbon combustion system 100 transfers carbon oxides (carbon dioxide: CO ₂ ) produced in the closed combustor 114 to the carbon oxide reservoir 102 (hydrocarbon generator 108) and water produced in the closed combustor 114. (H ₂ O) is returned to water reservoir 104 (electrolyzer 106). Thereby, the hydrocarbon combustion system 100 forms a closed cycle in which substances obtained by decomposing and synthesizing carbon oxide and water circulate. Note that the pressure in the closed cycle is the atmospheric pressure in the first embodiment. However, it is not limited to this, and the pressure within the closed cycle may be higher than the atmospheric pressure. By making the pressure in the closed cycle higher than the atmospheric pressure, the efficiency of hydrocarbon generation in the hydrocarbon generator 108 and the combustion efficiency in the closed combustor 114 can be improved.

Hydrocarbon combustion system 100 also includes controller 140 , carbon oxide valve 142 , water valve 144 , hydrocarbon valve 146 and oxygen valve 148 . The control device 140 is a microcomputer including a central processing unit (CPU), a ROM storing programs and the like, and a RAM as a work area. Controller 140 controls the entire hydrocarbon combustion system 100 .

FIG. 2 is a block diagram showing a schematic configuration of the control device 140 of the first embodiment. As shown in FIG. 2, in the first embodiment, the controller 140 functions as a carbon oxide supply controller 140a, a water supply controller 140b, a hydrocarbon supply controller 140c, and an oxygen supply controller 140d.

The carbon oxide supply control unit 140a controls the opening degree of the carbon oxide valve 142 via an actuator (not shown). The carbon oxide supply control unit 140a can control the carbon oxide valve 142 to be closed or open.

The water supply controller 140b controls the opening of the water valve 144 via an actuator (not shown). The water supply controller 140b can control the water valve 144 to be closed or open.

The hydrocarbon supply controller 140c controls the opening degree of the hydrocarbon valve 146 via an actuator (not shown). The hydrocarbon supply controller 140c can control the hydrocarbon valve 146 to be closed or open.

The oxygen supply controller 140d controls the opening of the oxygen valve 148 via an actuator (not shown). The oxygen supply controller 140d can control the oxygen valve 148 to be closed or open.

Returning to FIG. 1 , the carbon oxide valve 142 is arranged in the first pipe 118 . Carbon oxide valve 142 adjusts the amount of carbon oxide (CO ₂ in FIG. 1) to be supplied from carbon oxide reservoir 102 to hydrocarbon generator 108 by having its opening controlled by controller 140 .

A water valve 144 is arranged in the second pipe 120 . The water valve 144 adjusts the amount of water (2H ₂ O (4H ₂ O) in FIG. 1) supplied from the water reservoir 104 to the electrolytic device 106 by controlling the degree of opening thereof by the control device 140. .

A hydrocarbon valve 146 is arranged in the eighth pipe 132 . The opening of hydrocarbon valve 146 is controlled by controller 140 to adjust the amount of hydrocarbons (CH ₄ in FIG. 1) supplied from hydrocarbon reservoir 112 to closed combustor 114 .

An oxygen valve 148 is arranged in the fourth pipe 124 . The opening of oxygen valve 148 is controlled by control device 140 to adjust the amount of oxygen (2O ₂ in FIG. 1) supplied from electrolysis device 106 to closed combustor 114 .

That is, the hydrocarbon valve 146 can adjust the supply amount of hydrocarbons (CH ₄ in FIG. 1) generated from renewable energy to the closed combustor 114 . Hydrocarbon valve 146 may cause hydrocarbon reservoir 112 to store hydrocarbons by reducing the amount of hydrocarbons supplied to closed combustor 114 when heat demand is low. The hydrocarbon valve 146 can also release stored hydrocarbons to supply more hydrocarbons to the closed combustor 114 when heat demand is high to meet the heat demand.

Next, the action and operation of the hydrocarbon combustion system 100 will be described. When the operation of the hydrocarbon combustion system 100 is started, the carbon oxide supply control unit 140a controls the carbon oxide valve 142 to an open state, and the carbon oxide stored in the carbon oxide storage unit 102 (CO ₂ ) is fed to the hydrocarbon generator 108 .

Further, the water supply control unit 140b controls the water valve 144 to be in an open state, and causes the water stored in the water storage unit 104 (4H ₂ O in FIG. 1) to be supplied to the electrolytic device 106 .

As described above, power is supplied to the electrolyzer 106 from a power generator (not shown). The electrolytic device 106 applies a voltage to water (4H ₂ O in FIG. 1) to decompose it into hydrogen (4H ₂ in FIG. 1) and oxygen (2O ₂ in FIG. 1). Electrolyzer 106 supplies hydrogen (4H ₂ in FIG. 1) to hydrocarbon generator 108 and oxygen (2O ₂ in FIG. 1) to closed combustor 114 .

The hydrocarbon generator 108 includes a methanation reaction (4H ₂ + CO ₂ →CH ₄
+ 2H ₂ O) (for example, a nickel (Ni)-based catalyst, a ruthenium (Ru)-based catalyst, a platinum (Pt)-based catalyst, etc.) is accommodated. A heating device (not shown) is arranged in the hydrocarbon generator 108 . The heating device is temperature-controlled by the controller 140 and heats the hydrocarbon generator 108 until it reaches a predetermined catalyst activation temperature (temperature condition). When the hydrocarbon generator 108 is heated to a predetermined catalyst activation temperature, the catalyst reacts carbon oxide (CO ₂ in FIG. 1) and hydrogen (4H ₂ in FIG. 1) to produce hydrocarbons ( CH ₄ in the middle) and water (2H ₂ O in FIG. 1).

The hydrocarbon generator 108 supplies hydrocarbons and water to the gas-liquid separator 110 . At this time, the hydrocarbons and water are cooled by a cooling device (not shown), and the water is converted from gas (steam) to liquid (water).

The gas-liquid separation unit 110 separates hydrocarbons (CH ₄ in FIG. 1) and water (2H ₂ O in FIG. 1) into gas-liquid separation. The gas-liquid separation unit 110 supplies the separated hydrocarbon (CH ₄ in FIG. 1) to the hydrocarbon storage unit 112 and supplies the separated water (2H ₂ O in FIG. 1) to the electrolytic device 106 .

The hydrocarbon storage unit 112 stores hydrocarbons (CH ₄ in FIG. 1) when the hydrocarbon valve 146 is closed. The hydrocarbon reservoir 112 supplies the internally stored hydrocarbon (CH ₄ in FIG. 1) to the closed combustor 114 when the hydrocarbon valve 146 is open.

The hydrocarbon supply control unit 140c controls the opening degree of the hydrocarbon valve 146 according to the heat demand of the consumer (for example, the amount of heat required for heat treatment in the heating furnace). By controlling the degree of opening of hydrocarbon valve 146 , the amount of hydrocarbons supplied from hydrocarbon reservoir 112 to closed combustor 114 is controlled (adjusted).

At this time, the oxygen supply control unit 140d controls the opening degree of the oxygen valve 148 (that is, the supply amount of oxygen) according to the opening degree of the hydrocarbon valve 146 (that is, the supply amount of hydrocarbons). For example, the oxygen supply control unit 140d adjusts the opening degree of the oxygen valve 148 so that oxygen (O ₂ ) remaining in the combustion gas after the fuel is burned in the closed combustor 114 is reduced (no longer). (Control.

The closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 1) supplied from the hydrocarbon reservoir 112 and oxygen (2O ₂ in FIG. 1) supplied from the electrolytic device 106 . The closed combustor 114 produces heat by burning hydrocarbons (CH ₄ in FIG. 1) and oxygen (2O ₂ ). The closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 1) and oxygen (2O ₂ ) to produce carbon oxide (CO ₂ in FIG. 1) and water (2H ₂ O).

The closed combustor 114 supplies the generated heat to a heat demanding part (for example, a heating furnace) (not shown). The closed combustor 114 supplies the produced carbon oxide (CO ₂ in FIG. 1) and water (2H ₂ O) to the gas-liquid separator 116 . At this time, the carbon oxide and water are cooled by a cooling device (not shown), and the water is converted from gas (steam) to liquid (water).

The gas-liquid separation unit 116 separates carbon oxide (CO ₂ in FIG. 1) and water (2H ₂ O in FIG. 1) into gas and liquid. The gas-liquid separator 116 supplies the separated carbon oxide (CO ₂ in FIG. 1) to the carbon oxide reservoir 102 and supplies the separated water (2H ₂ O in FIG. 1) to the water reservoir 104 .

The carbon dioxide supply control unit 140a maintains the opening degree (open state) of the carbon dioxide valve 142 after the closed combustor 114 is activated. By maintaining the opening of the carbon oxide valve 142, the carbon oxide (CO ₂ in FIG. 1) supplied from the gas-liquid separation unit 116 to the carbon oxide storage unit 102 is converted into hydrocarbons from the carbon oxide storage unit 102. supplied to device 108 . In this way, the carbon oxides (CO ₂ in FIG. 1) produced in the closed combustor 114 pass through the gas-liquid separator 116, the carbon oxide reservoir 102 and the carbon oxide valve 142 to the hydrocarbon generator 108. will be supplied to

After the operation of the closed combustor 114, the water supply control unit 140b reduces the degree of opening of the water valve 144 while keeping it open. By keeping the water valve 144 open, the water (2H ₂ O in FIG. 1) supplied from the gas-liquid separation unit 116 to the water storage unit 104 is supplied from the water storage unit 104 to the electrolytic device 106. be done. Thus, the water (2H ₂ O in FIG. 1) generated in the closed combustor 114 is supplied to the electrolytic device 106 via the gas-liquid separator 116, the water reservoir 104 and the water valve 144. It will happen.

Here, the electrolytic device 106 is supplied with water (2H ₂ O in FIG. 1) from the gas-liquid separator 110 . Therefore, the water supply control unit 140b controls the opening degree of the water valve 144 to be small according to the amount of water (2H ₂ O in FIG. 1) supplied from the gas-liquid separation unit 110 . Specifically, the water supply control unit 140b controls the opening degree of the water valve 144 to be small, and reduces the amount of water supplied from the water storage unit 104 to the electrolysis device 106 compared to when the hydrocarbon combustion system 100 starts operating. Reduce to about half the amount (4H ₂ O to 2H ₂ O in FIG. 1).

Water supplied from the gas-liquid separator 110 (2H ₂ O in FIG. 1) and water supplied from the water reservoir 104 (2H ₂ O in FIG. 1) flow into the electrolytic device 106 . Therefore, the amount of water (4H ₂ O = 2H ₂ O + 2H ₂ O) supplied to the electrolysis device 106 from the gas-liquid separation unit 110 and the water storage unit 104 after the operation of the closed combustor 114 is The amount of water (4H ₂ O in FIG. 1) supplied from the water reservoir 104 to the electrolyzer 106 at the start of operation of .

Thus, the hydrocarbon combustion system 100 of the first embodiment returns (delivers) carbon oxide (CO ₂ in FIG. 1) produced in the closed combustor 114 to the hydrocarbon production device 108 . Further, the hydrocarbon combustion system 100 returns (delivers) water (2H ₂ O in FIG. 1) generated in the closed combustor 114 to the electrolytic device 106 . Further, the hydrocarbon combustion system 100 returns (delivers) the water (2H ₂ O in FIG. 1) separated by the gas-liquid separation section 110 to the electrolytic device 106 .

This eliminates the need for the hydrocarbon combustion system 100 to supply water to the electrolyzer 106 from outside the hydrocarbon combustion system 100 at any time in order for the electrolyzer 106 to generate hydrogen and oxygen. In addition, the hydrocarbon combustion system 100 does not need to supply carbon oxide to the hydrocarbon generator 108 from outside the hydrocarbon combustion system 100 at any time in order to generate hydrocarbons by the hydrocarbon generator 108 . Therefore, the hydrocarbon combustion system 100 can reduce costs compared to the case where water or hydrocarbons are supplied from outside the hydrocarbon combustion system 100 at any time when heat is generated by the closed combustor 114. can.

[Second embodiment]
FIG. 3 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 200 according to the second embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 100 of the first embodiment are denoted by the same reference numerals, and descriptions thereof are omitted. The hydrocarbon combustion system 200 of the second embodiment differs from the hydrocarbon combustion system 100 of the first embodiment in that the gas-liquid separator 110 is not provided.

Hydrocarbon combustion system 200 includes fifth line 226 instead of fifth line 126 and sixth line 128 of the first embodiment. Also, the hydrocarbon combustion system 200 includes a seventh pipe 230 instead of the seventh pipe 130 of the first embodiment. The hydrocarbon combustion system 200 includes a hydrocarbon reservoir 212 in place of the hydrocarbon reservoir 112 of the first embodiment.

A fifth pipe 226 is arranged between the hydrocarbon generator 108 and the hydrocarbon reservoir 212 . A fifth pipe 226 communicates between the hydrocarbon generator 108 and the hydrocarbon reservoir 212 . The hydrocarbon generator 108 supplies hydrocarbons (methane: CH ₄ in FIG. 3) and water (steam: 2H ₂ O in FIG. 3) to the hydrocarbon reservoir 212 via the fifth pipe 226 .

FIG. 4 is a schematic diagram of the hydrocarbon reservoir 212. As shown in FIG. As shown in FIG. 4, the hydrocarbon reservoir 212 is supplied with hydrocarbons (methane: CH ₄ in FIG. 4) and water (steam: 2H ₂ O in FIG. 4) from a fifth pipe 226 .

In the hydrocarbon reservoir 212, the hydrocarbon (methane) and water (steam) are naturally cooled and the water (steam) is liquefied. The liquefied water moves vertically downward in hydrocarbon reservoir 212 and is stored at the bottom of hydrocarbon reservoir 212 . Here, the hydrocarbon (methane) maintains a gaseous state without being liquefied even when naturally cooled.

A seventh pipe 230 is arranged vertically below the hydrocarbon reservoir 212 . A seventh pipe 230 communicates between the hydrocarbon reservoir 212 and the electrolytic device 106 . Therefore, the liquefied water is introduced into the seventh pipe 230 and returned to the electrolyzer 106 (see FIG. 3) via the seventh pipe 230 .

The seventh pipe 230 has a substantially S-shaped curved portion 230a. The curved portion 230a always retains liquefied water. That is, the seventh pipe 230 is sealed (water-sealed) by the water liquefied in the curved portion 230a. Accordingly, it is possible to suppress the supply of hydrocarbons (methane) in hydrocarbon reservoir 212 to electrolytic device 106 via seventh pipe 230 .

An eighth pipe 132 is arranged vertically above the hydrocarbon reservoir 212 . Hydrocarbons in hydrocarbon reservoir 212 are introduced into eighth pipe 132 and supplied to closed combustor 114 (see FIG. 3) via eighth pipe 132 .

Thus, in the hydrocarbon combustion system 200 of the second embodiment, the hydrocarbons (CH ₄ in FIG. 3) and water (2H ₂ O in FIG. 3) generated by the hydrocarbon generator 108 are Natural cooling occurs in piping 226 and hydrocarbon reservoir 212 . Accordingly, the hydrocarbon combustion system 200 does not include a cooling device for cooling the hydrocarbons (CH ₄ in FIG. 3) and water (2H ₂ O in FIG. 3) produced by the hydrocarbon generator 108. may Therefore, the hydrocarbon combustion system 200 can reduce costs compared to the hydrocarbon combustion system 100 of the first embodiment.

[Third embodiment]
FIG. 5 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 300 according to the third embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 100 of the first embodiment and the hydrocarbon combustion system 200 of the second embodiment are denoted by the same reference numerals, and description thereof is omitted. The hydrocarbon combustion system 300 of the third embodiment differs from the hydrocarbon combustion system 100 of the first embodiment and the hydrocarbon combustion system 200 of the second embodiment in that a reaction heat supply section (heat supply section) 302 is provided. ing.

As shown in FIG. 5 , a reaction heat supply section 302 is arranged between the hydrocarbon generator 108 and the hydrocarbon storage section 112 . Reaction heat supply 302 is in contact with hydrocarbon generator 108 and hydrocarbon reservoir 112 . However, reaction heat supply unit 302 does not have to be in contact with hydrocarbon generator 108 and hydrocarbon storage unit 112 . For example, the reaction heat supply section 302 may bring the member (fifth pipe 226 ) downstream of the hydrocarbon generator 108 into contact with the hydrocarbon storage section 112 . The reaction heat supply unit 302 is made of a heat transfer member such as copper, aluminum, graphite, or the like. The reaction heat supply unit 302 supplies the heat generated by the hydrocarbon generator 108 to the hydrocarbon storage unit 112 .

The hydrocarbon generator 108 generates hydrocarbons (methane: CH ₄ in the third embodiment). The methanation reaction in producing methane is exothermic. The reaction heat supply unit 302 supplies part of the reaction heat generated in the hydrocarbon generator 108 to the hydrocarbon storage unit 112 .

The hydrocarbon reservoir 112 is heated by the heat (reaction heat) supplied from the reaction heat supply section 302 . When hydrocarbon reservoir 112 is heated, the liquefied water (H ₂ O) within hydrocarbon reservoir 112 is vaporized.

As described above, the closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 5) and oxygen (2O ₂ in FIG. 5). At this time, the flame temperature of the closed combustor 114 becomes extremely high (for example, a temperature of 3000° C. or higher), and the closed combustor 114 may melt.

Therefore, in the third embodiment, the hydrocarbon storage section 112 supplies water (steam) vaporized by the heat supplied from the reaction heat supply section 302 to the closed combustor 114 . When the steam is supplied to the closed combustor 114, the temperature of the closed combustor 114 is lowered by the specific heat of the supplied steam.

Thus, in the third embodiment, hydrocarbon combustion system 300 includes reaction heat supply 302 . This allows the hydrocarbon combustion system 300 to supply vaporized water (steam) to the closed combustor 114 . As a result, the hydrocarbon combustion system 300 can reduce the temperature of the closed combustor 114 and suppress the erosion of the closed combustor 114 .

[Fourth embodiment]
FIG. 6 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 400 according to the fourth embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 100 of the first embodiment and the hydrocarbon combustion system 200 of the second embodiment are denoted by the same reference numerals, and description thereof is omitted. The hydrocarbon combustion system 400 of the fourth embodiment differs from the hydrocarbon combustion system 100 of the first embodiment and the hydrocarbon combustion system 200 of the second embodiment in that it includes a combustion heat supply section (heat supply section) 402. ing.

As shown in FIG. 6 , a combustion heat supply 402 is arranged between the hydrocarbon reservoir 112 and the closed combustor 114 . Combustion heat supply 402 is in contact with hydrocarbon reservoir 112 and closed combustor 114 . However, combustion heat supply 402 does not have to be in contact with hydrocarbon reservoir 112 and closed combustor 114 . For example, the combustion heat supply unit 402 may bring the hydrocarbon storage unit 112 into contact with a member (the ninth pipe 134 ) downstream of the closed combustor 114 . The combustion heat supply unit 402 is made of a heat transfer member such as copper, aluminum, graphite, or the like. Combustion heat supply 402 supplies heat produced in closed combustor 114 to hydrocarbon reservoir 112 .

In the closed combustor 114, heat (combustion heat) is generated by burning hydrocarbons (CH ₄ in FIG. 6) and oxygen (2O ₂ in FIG. 6). Combustion heat supply 402 supplies a portion of the heat produced in closed combustor 114 to hydrocarbon reservoir 112 .

Hydrocarbon storage portion 112 is heated by the heat (combustion heat) supplied from combustion heat supply portion 402 . When hydrocarbon reservoir 112 is heated, the liquefied water (H ₂ O) within hydrocarbon reservoir 112 is vaporized.

When the closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 6) and oxygen (2O ₂ in FIG. 6), the flame temperature of combustion (for example, a temperature of 3000° C. or higher) results in closed combustion. There is a risk that the container 114 will be melted.

In the fourth embodiment, the hydrocarbon reservoir 112 supplies vaporized water (steam) to the closed combustor 114 . When the steam is supplied to the closed combustor 114, the temperature of the closed combustor 114 is lowered by the specific heat of the supplied steam.

Thus, in the fourth embodiment, hydrocarbon combustion system 400 includes combustion heat supply 402 . This allows the hydrocarbon combustion system 400 to supply vaporized water (steam) to the closed combustor 114 . As a result, the hydrocarbon combustion system 400 can reduce the temperature of the closed combustor 114 and suppress the erosion of the closed combustor 114 .

[Fifth embodiment]
FIG. 7 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 500 according to the fifth embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 100 of the first embodiment are denoted by the same reference numerals, and descriptions thereof are omitted. A hydrocarbon combustion system 500 of the fifth embodiment has the same configuration as the hydrocarbon combustion system 100 of the first embodiment. However, the control of the carbon oxide valve 142 by the carbon oxide supply controller 140a (see FIG. 2) differs from that of the first embodiment.

As described above, when the closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 7) and oxygen (2O ₂ in FIG. 7), the flame temperature of combustion (for example, a temperature of 3000° C. or higher) As a result, the closed combustor 114 may be eroded.

In the fifth embodiment, the carbon oxide supply control unit 140a (see FIG. 2) controls the opening degree of the carbon oxide valve 142 according to the temperature of the closed combustor 114, and the oxygen gas supplied to the hydrocarbon generator 108 is supplied to the hydrocarbon generator 108. The supply amount of carbon (CO ₂ in FIG. 7) is controlled.

For example, hydrocarbon combustion system 500 may include a thermometer (not shown) that measures the temperature of closed combustor 114 . The carbon dioxide supply control unit 140a may control the opening degree of the carbon dioxide valve 142 based on the output of a thermometer (not shown). Further, the carbon oxide supply control unit 140a may estimate the temperature of the closed combustor 114 based on the opening degree of the hydrocarbon valve 146 ₍ that is, the amount of CH4 supplied). The carbon dioxide supply control unit 140a may control the opening degree of the carbon dioxide valve 142 based on the estimated temperature of the closed combustor 114 .

In the fifth embodiment, the carbon oxide supply control unit 140a increases the amount of carbon oxide supplied to the hydrocarbon generator 108 (“+nCO ₂ ” in FIG. 7) more than in the first embodiment. It controls the opening of the carbon valve 142 . In FIG. 7, "+" of "+nCO ₂ " indicates that more carbon oxide is supplied in addition to the carbon oxide required for the hydrocarbon generator 108 . The “n” in “+nCO ₂ ” indicates the amount of carbon oxides increased in addition to the carbon oxides required for the hydrocarbon generator 108 .

That is, the carbon oxide supply control unit 140a causes the hydrocarbon generator 108 to supply more carbon oxide than the carbon oxide required for the hydrocarbon generator 108 (that is, excess carbon oxide). Excess carbon oxide (“+nCO ₂ ” in FIG. 7) is supplied to closed combustor 114 via hydrocarbon generator 108 , gas-liquid separator 110 , and hydrocarbon reservoir 112 . When the excess carbon oxide is supplied to the closed combustor 114, the temperature of the closed combustor 114 is lowered by the specific heat of the supplied carbon oxide.

Excess carbon oxide (“+nCO ₂ ” in FIG. 7) supplied to the closed combustor 114 is returned from the closed combustor 114 to the carbon oxide reservoir 102 via the gas-liquid separator 116 . That is, excess carbon oxides circulate through hydrocarbon generator 108 , gas-liquid separation section 110 , hydrocarbon storage section 112 , closed combustor 114 , gas-liquid separation section 116 and carbon oxide storage section 102 . The carbon oxide supply control unit 140a controls the amount of carbon oxide circulating through the hydrocarbon generator 108, the gas-liquid separation unit 110, the hydrocarbon storage unit 112, the closed combustor 114, the gas-liquid separation unit 116, and the carbon oxide storage unit 102. to control. That is, the carbon oxide supply control unit 140a controls (adjusts) the circulation amount of carbon oxide indicated by “+nCO ₂ ” in FIG.

Thus, in the fifth embodiment, the carbon oxide supply control unit 140a causes the closed combustor 114 to supply excess carbon oxide (“+nCO ₂ ” in FIG. 7). As a result, the hydrocarbon combustion system 500 can lower the temperature of the closed combustor 114 and suppress the erosion of the closed combustor 114 .

[Sixth Embodiment]
FIG. 8 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 600 according to the sixth embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 300 of the third embodiment are denoted by the same reference numerals, and description thereof is omitted. A hydrocarbon combustion system 600 of the sixth embodiment has the same configuration as the hydrocarbon combustion system 300 of the third embodiment. However, the control of the water valve 144 by the water supply controller 140b (see FIG. 2) differs from that of the third embodiment.

As described above, when the closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 8) and oxygen (2O ₂ in FIG. 8), the flame temperature of combustion (for example, a temperature of 3000° C. or higher) As a result, the closed combustor 114 may be eroded.

In the sixth embodiment, the water supply control unit 140b (see FIG. 2) controls the opening degree of the water valve 144 according to the temperature of the closed combustor 114, and the water supplied to the electrolytic device 106 ( , 2H ₂ O (4H ₂ O)).

For example, hydrocarbon combustion system 600 may include a thermometer (not shown) that measures the temperature of closed combustor 114 . The water supply controller 140b may control the degree of opening of the water valve 144 based on the output of a thermometer (not shown). Also, the water supply control unit 140b may estimate the temperature of the closed combustor 114 based on the degree of opening of the hydrocarbon valve 146 ₍ that is, the amount of CH4 supplied). The water supply control unit 140b may control the degree of opening of the water valve 144 based on the estimated temperature of the closed combustor 114 .

In the sixth embodiment, the water supply control unit 140b controls the water valve 144 so that the amount of water supplied to the electrolytic device 106 is increased (“+nH ₂ O” in FIG. 8) more than in the third embodiment. controlling the opening. In FIG. 8, the "+" in "+nH ₂ O" indicates that more water is supplied in addition to the water required for the electrolytic device 106. The “n” in “+nH ₂ O” indicates the amount of water added to the water required for the electrolyzer 106 .

That is, the water supply control unit 140b causes the electrolysis device 106 to supply more water than the water required for the electrolysis device 106 (that is, excess water). Excess water (“+nH ₂ O” in FIG. 8) is supplied to closed combustor 114 via electrolyzer 106 . When excess water is supplied to the closed combustor 114, the temperature of the closed combustor 114 is lowered by the specific heat of the supplied water.

Excess water (“+nH ₂ O” in FIG. 8 ) supplied to closed combustor 114 is returned from closed combustor 114 to water reservoir 104 via gas-liquid separator 116 . That is, excess water circulates through the electrolytic device 106 , the closed combustor 114 , the gas-liquid separator 116 and the water reservoir 104 . Water supply control unit 140 b controls the amount of water circulating through electrolysis device 106 , closed combustor 114 , gas-liquid separation unit 116 and water storage unit 104 . That is, the water supply control unit 140b controls (adjusts) the circulation amount of water indicated by “+nH ₂ O” in FIG.

Thus, in the sixth embodiment, the water supply controller 140b causes the closed combustor 114 to supply excess water (“+nH ₂ O” in FIG. 8). Thereby, the hydrocarbon combustion system 600 can lower the temperature of the closed combustor 114 and can suppress the erosion of the closed combustor 114 .

[Seventh Embodiment]
FIG. 9 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 700 according to the seventh embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 300 of the third embodiment are denoted by the same reference numerals, and description thereof is omitted. The hydrocarbon combustion system 700 of the seventh embodiment differs from the hydrocarbon combustion system 300 of the third embodiment in that it includes a circulation pipe 702 and a combustion gas valve 704, and in that it includes a controller 740 instead of the controller 140. there is

As shown in FIG. 9 , a circulation pipe 702 is connected to the closed combustor 114 . One end of the circulation pipe 702 is connected to the upstream side of the closed combustor 114 (hydrocarbon reservoir 112 side), and the other end is connected to the downstream side of the closed combustor 114 (gas-liquid separator 116 side). . However, one end of the circulation pipe 702 may be connected to the upstream side of the closed combustor 114 and the other end may not be connected to the downstream side of the closed combustor 114 . For example, one end of the circulation pipe 702 is connected to a member (eighth pipe 132) upstream of the closed combustor 114, and the other end is connected to a member (ninth pipe 134) downstream of the closed combustor 114. may be connected to

The circulation pipe 702 circulates a portion of the combustion gas discharged from the downstream side of the closed combustor 114 to the upstream side of the closed combustor 114 . Here, the circulation pipe 702 may include an ejector (not shown) in order to circulate part of the combustion gas.

A combustion gas valve 704 is arranged in the circulation pipe 702 . The opening of combustion gas valve 704 is controlled by control device 740 to adjust the flow rate of the combustion gas flowing back from the downstream side of closed combustor 114 to the upstream side of closed combustor 114 .

FIG. 10 is a block diagram showing a schematic configuration of the control device 740 of the seventh embodiment. As shown in FIG. 10, in the seventh embodiment, the control device 740 functions as a carbon oxide supply control section 140a, a water supply control section 140b, a hydrocarbon supply control section 140c, and a combustion gas supply control section 740e. .

The combustion gas supply control section 740e controls the opening degree of the combustion gas valve 704 via an actuator (not shown). The combustion gas supply control section 740e can control the combustion gas valve 704 to be closed or open. The combustion gas supply control unit 740e can adjust the flow rate of the combustion gas that flows back from the downstream side of the closed combustor 114 to the upstream side of the closed combustor 114 by controlling the opening degree of the combustion gas valve 704. .

When the closed combustor 114 burns hydrocarbons (CH ₄ in FIG. 9) and oxygen (2O ₂ in FIG. 9), the flame temperature of combustion (for example, a temperature of 3000° C. or higher) results in closed combustion. There is a risk that the container 114 will be melted.

In the seventh embodiment, the combustion gas supply control unit 740e controls the opening degree of the combustion gas valve 704 to control the combustion gas (CO ₂ and 4H ₂ O in FIG. 9) generated in the closed combustor 114. A part of it is circulated to the upstream side of the closed combustor 114 through a circulation pipe 702 . When part of the combustion gas is supplied to the closed combustor 114, the temperature is lowered by the specific heat of the supplied combustion gas (CO ₂ and H ₂ O).

Thus, in the seventh embodiment, the hydrocarbon combustion system 700 includes the circulation pipe 702, the combustion gas valve 704, and the combustion gas supply controller 740e. This allows the hydrocarbon combustion system 700 to provide a portion of the combustion gases to the closed combustor 114 . As a result, the hydrocarbon combustion system 700 can reduce the temperature of the closed combustor 114 and suppress the erosion of the closed combustor 114 .

(Eighth embodiment)
FIG. 11 is a diagram illustrating a schematic configuration of a hydrocarbon combustion system 800 according to the eighth embodiment. Components that are substantially the same as those of the hydrocarbon combustion system 300 of the third embodiment are denoted by the same reference numerals, and description thereof is omitted. A hydrocarbon combustion system 800 of the eighth embodiment includes an electrolytic device 806 instead of the electrolytic device 106, a combustion gas reservoir 804 instead of the water reservoir 104, and a combustion gas valve 844 instead of the water valve 144. and a control device 840 instead of the control device 140, which is different from the third embodiment.

The combustion gas reservoir 804 stores the combustion gas (carbon dioxide: CO ₂ and water: 3H ₂ O in the eighth embodiment) delivered from the closed combustor 114 . A predetermined amount of combustion gas (CO ₂ and 3H ₂ O in FIG. 11) is stored in advance in combustion gas reservoir 804 before operating hydrocarbon combustion system 800 for the first time. However, the combustion gas reservoir 804 may be supplied with a predetermined amount of combustion gas (CO ₂ and 3H ₂ O in FIG. 11) from the outside when the hydrocarbon combustion system 800 is operated for the first time. .

The combustion gas reservoir 804 has a heating device (not shown). When the hydrocarbon combustion system 800 starts operating, the heating device heats the carbon dioxide (CO ₂ in FIG. 11) and water (3H ₂ O in FIG. 11) stored in the combustion gas storage unit 804 to 500° C., for example. Heat to above. Combustion gas reservoir 804 supplies heated carbon dioxide and water (steam) to electrolyzer 806 .

Further, after the hydrocarbon combustion system 800 starts operating, the combustion gas reservoir 804 supplies the combustion gas (CO ₂ and 3H ₂ O in FIG. 11) delivered from the closed combustor 114 to the electrolytic device 806 . The combustion gas reservoir 804 can supply carbon oxide and water required for driving the electrolytic device 806 to the electrolytic device 806 at any timing.

Electrolyzer 806 is connected to a power generator (not shown) that generates power from renewable energy. Electric power is supplied to the electrolytic device 806 from a power generator (not shown). Further, combustion gas (CO ₂ and 3H ₂ O in FIG. 11) is supplied to the electrolytic device 806 from a combustion gas reservoir 804 .

In the eighth embodiment, the electrolytic device 806 includes, for example, a solid oxide electrolysis cell (SOEC: Solid Oxide Electrolysis Cell), which electrolyzes carbon dioxide and water (co-electrolysis) to produce hydrogen and monoxide. Can be converted into carbon and oxygen. The electrolytic device 106 converts carbon monoxide (CO in FIG. 11), hydrogen (3H ₂ in FIG. 11), and oxygen (FIG. 11) from the supplied electric power and combustion gas (CO ₂ and 3H ₂ O in FIG. 11, 2O ₂ ).

The electrolytic device 806 supplies carbon monoxide (CO in FIG. 11) and hydrogen (3H ₂ in FIG. 11) to the hydrocarbon generator 108 via the third pipe 122 . Further, the electrolytic device 806 supplies oxygen (2O ₂ in FIG. 11) to the closed combustor 114 through the fourth pipe 124 .

The hydrocarbon generator 108 produces hydrocarbons (CH ₄ in _FIG . 11) and water (H ₂ O). In the eighth embodiment, the hydrocarbon generator 108 is producing methane and steam.

Specifically, the hydrocarbon generator 108 has a methanation reaction (3H ₂ + CO →
A catalyst (for example, a nickel (Ni)-based catalyst, a ruthenium (Ru)-based catalyst, a platinum (Pt)-based catalyst, etc.) that activates CH ₄ +H ₂ O) is accommodated. A heating device (not shown) is arranged in the hydrocarbon generator 108 . The heating device is temperature-controlled by the controller 840 and heats the hydrocarbon generator 108 until it reaches a predetermined catalyst activation temperature (temperature condition). When the hydrocarbon generator 108 is heated to a predetermined catalyst activation temperature, the catalyst reacts carbon monoxide (CO in FIG. 11) and hydrogen (3H ₂ in FIG. 11) to produce hydrocarbons (CO in FIG. 11). medium, CH ₄ ) and water (H ₂ O in FIG. 11).

FIG. 12 is a block diagram showing a schematic configuration of the control device 840 of the eighth embodiment. As shown in FIG. 12, in the eighth embodiment, the controller 840 functions as a combustion gas supply controller 840a and a hydrocarbon supply controller 140c.

The combustion gas supply control section 840a controls the opening degree of the combustion gas valve 844 via an actuator (not shown). The combustion gas supply control section 840a can control the combustion gas valve 844 to be closed or open. The combustion gas supply control unit 840 a can adjust the amount of combustion gas supplied from the combustion gas reservoir 804 to the electrolytic device 806 by controlling the opening of the combustion gas valve 844 . At this time, the combustion gas supply control unit 840a controls to supply excess carbon oxide or water to the closed combustor 114 to lower the temperature of the closed combustor 114, as in the fifth and sixth embodiments. You may

Thus, in the eighth embodiment, the closed combustor 114 returns combustion gases (i.e., carbon oxides (CO ₂ in FIG. 11) and water (3H ₂ O in FIG. 11)) to the electrolyzer 806. (sending).

Accordingly, in order for the hydrocarbon combustion system 800 to generate carbon monoxide, hydrogen, and oxygen by the electrolysis device 806, it is necessary to supply carbon oxide and water to the electrolysis device 806 from outside the hydrocarbon combustion system 800 at any time. Gone. Therefore, the hydrocarbon combustion system 800 can reduce costs compared to supplying water or hydrocarbons from outside the hydrocarbon combustion system 800 as needed when heat is generated by the closed combustor 114. can.

Also, in the hydrocarbon combustion system 800 of the eighth embodiment, the electrolyzer 806 can generate carbon monoxide, hydrogen, and oxygen from the combustion gas. Therefore, the hydrocarbon combustion system 800 does not have to be provided with the gas-liquid separator 116 for separating carbon oxide (CO ₂ in FIG. 11) and water (3H ₂ O in FIG. 11) contained in the combustion gas. good too. Therefore, the hydrocarbon combustion system 800 can reduce costs compared to the hydrocarbon combustion system 100 of the first embodiment.

Although the embodiments of the present disclosure have been described above with reference to the accompanying drawings, it goes without saying that the present disclosure is not limited to such embodiments. It is clear that a person skilled in the art can conceive of various modifications or modifications within the scope of the claims, and it is understood that these also belong to the technical scope of the present disclosure. be done.

In the above first to seventh embodiments, examples in which the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, and 700 include the carbon oxide reservoir 102 have been described. However, the carbon oxide reservoir 102 is not an essential component. Accordingly, hydrocarbon combustion systems 100 , 200 , 300 , 400 , 500 , 600 , 700 may not include carbon oxide reservoir 102 .

In the above-described first to seventh embodiments, the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, 700 are provided with the carbon oxide valve 142 and the carbon oxide supply controller 140a. However, the carbon oxide valve 142 and the carbon oxide supply control unit 140a are not essential components. Accordingly, the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, 700 may not include the carbon oxide valve 142 and the carbon oxide supply controller 140a.

In the above first to seventh embodiments, the examples in which the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, and 700 include the water reservoir 104 have been described. However, the water reservoir 104 is not an essential component. Accordingly, hydrocarbon combustion systems 100 , 200 , 300 , 400 , 500 , 600 , 700 may not include water reservoir 104 .

In the above-described first to seventh embodiments, the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, 700 are provided with the water valve 144 and the water supply controller 140b. However, the water valve 144 and the water supply controller 140b are not essential components. Accordingly, hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, 700 may not include water valve 144 and water supply control 140b.

In the eighth embodiment described above, the hydrocarbon combustion system 800 has an example in which the combustion gas reservoir 804 is provided. However, the combustion gas reservoir 804 is not an essential component. Accordingly, hydrocarbon combustion system 800 may not include combustion gas reservoir 804 .

In the above eighth embodiment, the example in which the hydrocarbon combustion system 800 includes the combustion gas valve 844 and the combustion gas supply control section 840a has been described. However, the combustion gas valve 844 and the combustion gas supply control section 840a are not essential components. Therefore, the hydrocarbon combustion system 800 does not have to include the combustion gas valve 844 and the combustion gas supply controller 840a.

Further, the hydrocarbon combustion systems 100, 200, 300, 400, 500, 600, 700, 800 of each of the above embodiments can be combined. For example, the hydrocarbon combustion system 300 of the third embodiment may include the combustion heat supply section 402 of the fourth embodiment. Further, the hydrocarbon combustion system 300 of the third embodiment may include the circulation pipe 702, the combustion gas valve 704, and the combustion gas supply controller 740e of the seventh embodiment. Further, the hydrocarbon combustion system 800 of the eighth embodiment may include the reaction heat supply section 302 of the third embodiment. Further, the hydrocarbon combustion system 800 of the eighth embodiment may include the combustion heat supply section 402 of the fourth embodiment. Further, the hydrocarbon combustion system 800 of the eighth embodiment may include the circulation pipe 702, the combustion gas valve 704, and the combustion gas supply controller 740e of the seventh embodiment.

The present disclosure may be utilized in hydrocarbon combustion systems.

100: Hydrocarbon combustion system 102: Carbon oxide reservoir 104: Water reservoir 106: Electrolyzer 108: Hydrocarbon generator 112: Hydrocarbon reservoir 114: Closed combustor 116: Gas-liquid separator (separator) 140a : Carbon oxide supply control unit 140b: Water supply control unit 300: Hydrocarbon combustion system 302: Reaction heat supply unit (heat supply unit) 400: Hydrocarbon combustion system 402: Combustion heat supply unit (heat supply unit) 700: Hydrocarbon Combustion system 702: Circulation pipe 800: Hydrocarbon combustion system 804: Combustion gas reservoir 840a: Combustion gas supply controller

Claims (11)

an electrolyzer that produces hydrogen using power generated from renewable energy;
a hydrocarbon generator that generates hydrocarbons using the hydrogen generated by the electrolyzer and carbon dioxide;
a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator;
a closed combustor for burning the hydrocarbons taken from the hydrocarbon reservoir;
a separation unit that separates carbon dioxide and water generated by combustion of the hydrocarbons, sends the carbon dioxide to the hydrocarbon generator and sends the water to the electrolysis device;
a heat supply unit that supplies the heat generated by the hydrocarbon generator to the hydrocarbon storage unit;
A hydrocarbon combustion system comprising: an electrolyzer that produces hydrogen using power generated from renewable energy;
a hydrocarbon generator that generates hydrocarbons using the hydrogen generated by the electrolyzer and carbon dioxide;
a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator;
a closed combustor for burning the hydrocarbons taken from the hydrocarbon reservoir;
a separation unit that separates carbon dioxide and water generated by combustion of the hydrocarbons, sends the carbon dioxide to the hydrocarbon generator and sends the water to the electrolysis device;
a heat supply unit that supplies heat generated in the closed combustor to the hydrocarbon storage unit;
A hydrocarbon combustion system comprising: 3. The hydrocarbon combustion system according to claim 1 or 2 , further comprising a carbon oxide storage section that stores the carbon dioxide sent from the separation section. 4. The method according to any one of claims 1 to 3, further comprising a carbon oxide supply control unit that controls the amount of the carbon dioxide circulating through the hydrocarbon generator, the hydrocarbon reservoir, the closed combustor, and the separation unit. A hydrocarbon combustion system as described. 5. The hydrocarbon combustion system according to any one of claims 1 to 4 , further comprising a water storage section for storing the water delivered from the separation section. The hydrocarbon combustion system according to any one of claims 1 to 5 , further comprising a water supply control section for controlling the amount of water circulating through the electrolytic device, the closed combustor, and the separation section. an electrolyser that produces hydrogen and carbon monoxide using power generated from renewable energy;
a hydrocarbon generator for generating hydrocarbons using the hydrogen and the carbon monoxide generated by the electrolytic device;
a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator;
a closed combustor that burns the hydrocarbons taken from the hydrocarbon reservoir and delivers carbon dioxide and water to the electrolyzer;
a heat supply unit that supplies the heat generated by the hydrocarbon generator to the hydrocarbon storage unit;
A hydrocarbon combustion system comprising: an electrolyser that produces hydrogen and carbon monoxide using power generated from renewable energy;
a hydrocarbon generator for generating hydrocarbons using the hydrogen and the carbon monoxide generated by the electrolytic device;
a hydrocarbon reservoir for storing the hydrocarbons generated by the hydrocarbon generator;
a closed combustor that burns the hydrocarbons taken from the hydrocarbon reservoir and delivers carbon dioxide and water to the electrolyzer;
a heat supply unit that supplies heat generated in the closed combustor to the hydrocarbon storage unit;
A hydrocarbon combustion system comprising: 9. The hydrocarbon combustion system according to claim 7 , further comprising a combustion gas reservoir for storing the carbon dioxide and the water delivered from the closed combustor. 10. The combustion gas supply controller for controlling the amount of the carbon dioxide and the water circulating through the electrolytic device, the hydrocarbon generator, the hydrocarbon reservoir, and the closed combustor . 2. The hydrocarbon combustion system of claim 1 . The hydrocarbon combustion system according to any one of claims 1 to 10, further comprising a circulation pipe that recirculates part of the combustion gas discharged from the downstream side of the closed combustor to the upstream side of the closed combustor. .

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