Cogeneration power generation system

Abstract

To provide a cogeneration power generation system capable of improving total theoretical efficiency obtained by combining power generation efficiency accompanying a power generation amount and heat recovery efficiency accompanying effective use of a heat amount of combustion gas.SOLUTION: The cogeneration system 1 of the embodiment includes a compressor 15 that compresses steam, a combustor 20 that combusts oxygen and hydrogen to generate steam and heats the steam introduced from the compressor 15, a turbine 30 into which the steam discharged from the combustor 20 is introduced, a steam circulation pipe 60 that introduces the steam discharged from the turbine 30 into the compressor 15, a cooler 50 that supplies water into the steam circulation pipe 60 to cool the steam, and an extraction pipe 70 that is connected to the steam circulation pipe 60 at a connection portion 61 and extracts a part of the steam.SELECTED DRAWING: Figure 1

Description

[Technical Field]

[0001] FIELD OF THE INVENTION An embodiment of the present invention relates to a cogeneration power generation system. [Background technology]

[0002] A cogeneration power generation system (combined heat and power system) is a system that generates electricity using a power generation device and recovers the waste heat generated during the power generation process. Natural gas, oil, liquefied petroleum gas (LP gas), etc. are used as fuel for generating electricity. The power generation device may use a gas turbine, gas engine, diesel engine, or fuel cell.

[0003] In a cogeneration power generation system, the recovered waste heat is used to generate steam and hot water, which are then used as a heat source in factories, for heating and cooling, and for hot water supply.

[0004] FIG. 18 is a system diagram that schematically shows the configuration of a conventional cogeneration power generation system 200 that uses a gas turbine. As shown in FIG. 18, atmospheric air is drawn into a compressor 210, compressed, and supplied to a combustor 211. In the combustor 211, natural gas (city gas) supplied as fuel is combusted with the air. The high-temperature combustion gas generated in the combustor 211 is introduced into a turbine 212.

[0005] In the turbine 212, thermal energy of the combustion gas is converted into rotational energy to drive the turbine 212. The generator 213 is coaxially coupled to the turbine 212. In the generator 213, the rotational energy in the turbine 212 is converted into electrical energy to generate electricity.

[0006] The combustion gas discharged from the turbine 212 is introduced into a heat recovery boiler 214. Water pressurized by a pump 215 is also supplied to the heat recovery boiler 214. In the heat recovery boiler 214, the water is given heat from the combustion gas and becomes steam.

[0007] The steam generated in the heat recovery boiler 214 is supplied as a heat source to steam utilization equipment 217 such as a factory via a steam supply pipe 216. On the other hand, the combustion gas that has given heat to the water is discharged as exhaust gas into the atmosphere via an exhaust pipe 218.

[0008] In recent years, a technique has been considered in which the fuel supplied to the combustor 211 is replaced with hydrogen so that CO2 is not generated in the combustion gas. [Prior art documents] [Patent documents]

[0009] [Patent Document 1] Japanese Patent Application Laid-Open No. 2002-129985 Summary of the Invention [Problem to be solved by the invention]

[0010] In a cogeneration power generation system, if the generated thermal energy and electrical energy can be utilized without waste, high overall energy efficiency can be achieved. However, in conventional cogeneration power generation systems, the calorific value of the combustion gas is utilized to generate steam in the heat recovery boiler 214, but a certain amount of the calorific value of the combustion gas is discharged to the outside of the system as exhaust gas. This discharged heat from the heat recovery boiler 214 becomes a heat loss in the thermal cycle.

[0011] The problem that the present invention aims to solve is to provide a cogeneration power generation system that can improve overall theoretical efficiency, which is the combination of power generation efficiency associated with the amount of power generated and heat recovery efficiency associated with the effective use of the heat content of combustion gas. [Means for solving the problem]

[0012] The cogeneration power generation system of one embodiment includes a compressor that compresses steam, a combustor that burns oxygen and hydrogen to generate steam and heats the steam introduced from the compressor, a first turbine into which steam discharged from the combustor is introduced, a steam circulation pipe that introduces steam discharged from the first turbine into the compressor, a first cooler that supplies water into the steam circulation pipe to cool the steam, and a first extraction pipe that is connected to the steam circulation pipe at a first connection and extracts a portion of the steam. [Brief explanation of the drawings]

[0013] [Figure 1] 1 is a system diagram schematically illustrating a configuration of a cogeneration power generation system according to a first embodiment. [Figure 2] FIG. 2 is a Ts diagram schematically showing the heat cycle of the cogeneration power generation system of the first embodiment. [Figure 3] FIG. 10 is a system diagram schematically illustrating the configuration of a cogeneration power generation system according to a second embodiment. [Figure 4] FIG. 10 is a Ts diagram schematically showing a heat cycle of a cogeneration power generation system according to a second embodiment. [Figure 5] FIG. 10 is a system diagram schematically illustrating the configuration of a cogeneration power generation system according to a third embodiment. [Figure 6] FIG. 11 is a Ts diagram schematically showing a heat cycle of a cogeneration power generation system according to a third embodiment. [Figure 7] FIG. 10 is a system diagram schematically showing the configuration of a cogeneration power generation system according to a fourth embodiment. [Figure 8] FIG. 10 is a system diagram schematically illustrating the configuration of a cogeneration power generation system according to a fifth embodiment. [Figure 9] FIG. 10 is a system diagram schematically showing another configuration of the cogeneration power generation system according to the fifth embodiment. [Figure 10] FIG. 10 is a system diagram schematically illustrating the configuration of a cogeneration power generation system according to a sixth embodiment. [Figure 11] FIG. 13 is a Ts diagram schematically showing a heat cycle of a cogeneration power generation system according to a sixth embodiment. [Figure 12] FIG. 13 is a system diagram schematically showing the configuration of a cogeneration power generation system according to a seventh embodiment. [Figure 13] FIG. 13 is a Ts diagram schematically showing a heat cycle of a cogeneration power generation system according to a seventh embodiment. [Figure 14] FIG. 13 is a system diagram schematically showing the configuration of a cogeneration power generation system according to an eighth embodiment. [Figure 15] FIG. 13 is a system diagram schematically showing the configuration of a cogeneration power generation system according to a ninth embodiment. [Figure 16] FIG. 22 is a system diagram schematically illustrating the configuration of a cogeneration power generation system according to a tenth embodiment. [Figure 17] FIG. 22 is a system diagram schematically showing the configuration of a cogeneration power generation system according to an eleventh embodiment. [Figure 18] FIG. 1 is a system diagram schematically illustrating the configuration of a conventional cogeneration power generation system using a gas turbine. DETAILED DESCRIPTION OF THE INVENTION

[0014] Hereinafter, an embodiment of the present invention will be described with reference to the drawings.

[0015] (First embodiment) Fig. 1 is a system diagram that schematically illustrates the configuration of a cogeneration power generation system 1 according to a first embodiment. As shown in Fig. 1, the cogeneration power generation system 1 includes, as main components, a compressor 15, a combustor 20, a turbine 30, a generator 40, and a cooler 50. The turbine 30 functions as a first turbine, and the cooler 50 functions as a first cooler.

[0016] The compressor 15 is arranged on the same axis as the turbine 30 and the generator 40. The rotors of the compressor 15, the turbine 30, and the generator 40 are configured to rotate integrally.

[0017] The compressor 15 compresses the steam introduced through the steam circulation pipe 60. The steam compressed by the compressor 15 is guided to the combustor 20.

[0018] The combustor 20 generates steam by burning oxygen and hydrogen, and heats the steam introduced from the compressor 15. The combustor 20 includes a hydrogen supply pipe 21 that supplies hydrogen and an oxygen supply pipe 22 that supplies oxygen. In the combustor 20, water vapor is generated as combustion gas. The combustor 20 also heats the steam introduced from the compressor 15 with the generated water vapor.

[0019] Here, the flow rates of oxygen and hydrogen supplied to the combustor 20 are adjusted appropriately based on, for example, the set temperature of the steam to be generated. The flow rates of oxygen and hydrogen are adjusted, for example, to a stoichiometric mixture ratio (equivalence ratio of 1). Note that the equivalence ratio referred to here is an equivalence ratio calculated based on the fuel flow rate and the oxygen flow rate.

[0020] The flow rates of oxygen and hydrogen are adjusted to a stoichiometric mixture ratio, so the medium discharged from the combustor 20 is steam. The temperature of the steam discharged from the combustor 20 is higher than the temperature of the steam introduced from the compressor 15. Furthermore, the flow rate of the steam discharged from the combustor 20 is greater than the flow rate of the steam introduced from the compressor 15 by the amount of steam generated by combustion.

[0021] Steam discharged from the combustor 20 is introduced into the turbine 30. The turbine 30 is driven by converting the thermal energy of the steam into rotational energy. As the thermal energy of the steam is converted into rotational energy within the turbine 30, the temperature and pressure of the steam decrease. In the generator 40, which is coaxially coupled to the turbine 30, the rotational energy of the turbine 30 is converted into electrical energy to generate electricity.

[0022] The steam discharged from the turbine 30 is introduced into the compressor 15 through the steam circulation pipe 60. That is, the steam discharged from the turbine 30 is circulated to the compressor 15.

[0023] An extraction pipe 70 is connected to the steam circulation pipe 60 at a connection part 61. For example, as shown in FIG. 1 , the extraction pipe 70 is connected to the steam circulation pipe 60 between the cooler 50 and the turbine 30 at the connection part 61. The extraction pipe 70 extracts a part of the steam flowing through the steam circulation pipe 60. The extraction pipe 70 functions as a first extraction pipe, and the connection part 61 functions as a first connection part.

[0024] Here, the bleed pipe 70 is not limited to being connected to the steam circulation piping 60 between the cooler 50 and the turbine 30. In other words, the connection portion 61 is not limited to being located on the steam circulation piping 60 between the cooler 50 and the turbine 30. The bleed pipe 70 may be connected to the steam circulation piping 60 between the cooler 50 and the compressor 15, for example. In other words, the connection portion 61 may be located on the steam circulation piping 60 between the cooler 50 and the compressor 15. That is, the bleed pipe 70 is connected to any position on the steam circulation piping 60 that connects the turbine 30 and the compressor 15.

[0025] For example, when extraction steam at approximately the superheated steam temperature is required, the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the turbine 30. For example, when extraction steam at approximately the saturation temperature is required, the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the compressor 15. In this way, the position of the connection part 61 is changed appropriately depending on the required temperature of the extraction steam.

[0026] The steam extracted by the extraction pipe 70 is used as steam for heat utilization. For example, the steam extracted by the extraction pipe 70 is adjusted to the required temperature and pressure as appropriate and used as a heat source for a factory, etc.

[0027] The cooler 50 cools the steam by supplying water into the steam circulation pipe 60. The cooler 50 is provided in the steam circulation pipe 60 between the connection part 61 and the compressor 15. Water is supplied to the cooler 50 via a water supply pipe 51. The cooler 50 sprays water directly onto the steam flowing in the steam circulation pipe 60. The cooler 50 includes, for example, an injection nozzle that sprays water. The sprayed water is heated by the steam flowing in the steam circulation pipe 60 and turns into steam. All of the sprayed water turns into steam.

[0028] As a result, the temperature of the steam in the steam circulation pipe 60 decreases, and the flow rate of the steam increases by the amount of water that has turned into steam. Then, the steam cooled by the cooler 50 and the steam generated by the cooler are introduced into the compressor 15.

[0029] The flow rate of water supplied to the cooler 50 is adjusted based on, for example, the set temperature of the steam at the inlet of the compressor 15. The power of the compressor 15 decreases as the steam temperature at the inlet of the compressor 15 decreases. When the power of the compressor 15 is small, the output of the generator 40 obtained by subtracting the power of the compressor 15 from the output of the turbine 30 increases. By adjusting the flow rate of water supplied to the cooler 50, the steam temperature at the inlet of the compressor 15 can be adjusted, and the power generation output can also be adjusted.

[0030] The cogeneration power generation system 1 is a closed-cycle system in which steam, a working fluid, circulates through a cycle. Therefore, the pressure at the outlet of the turbine 30 can be set arbitrarily. The pressure at the outlet of the turbine 30 is set to a predetermined value depending on the use of the steam extracted from the extraction pipe 70. The temperature of the steam discharged from the turbine 30 is set, for example, based on the heat-resistant temperature of the material constituting the steam circulation piping 60. Here, the steam as the working fluid is saturated steam or superheated steam. The steam at the inlet of the compressor 15 may be, for example, wet steam.

[0031] In addition, in the cogeneration power generation system 1, in a steady operating state, the sum of the amount of steam generated in the cooler 50 and the amount of steam generated by oxygen-hydrogen combustion in the combustor 20 is equal to the amount of steam extracted from the extraction pipe 70.

[0032] Next, the heat cycle of the cogeneration power generation system 1 of the first embodiment will be described.

[0033] Fig. 2 is a Ts diagram that schematically shows the thermal cycle of the cogeneration power generation system 1 of the first embodiment. The horizontal axis of Fig. 2 represents the specific entropy s (kJ / (kg·K)) of the working fluid, and the vertical axis represents the temperature T (K) of the working fluid.

[0034] In Fig. 2, for example, starting from state a, the thermal cycle progresses in the order of state a, state b, state c, state d, and state a. The process from state a to state b shows the compression process in the compressor 15. The process from state b to state c shows the isobaric heating process in the combustor 20. Between state b and state c, a heat input q1 is generated by the combustion of oxygen and hydrogen. The process from state c to state d shows the expansion process in the turbine 30. The process from state d to state a shows the isobaric cooling process in the steam circulation piping 60 (cooler 50).

[0035] That is, steam in state a becomes steam in state b after undergoing a compression process in the compressor 15. Steam in state b receives heat input q1 in an isobaric heating process in the combustor 20 and becomes steam in state c. Steam in state c becomes steam in state d after undergoing an expansion process in the turbine 30. Steam in state d becomes steam in state a after undergoing an isobaric cooling process in the steam circulation piping 60 (cooler 50).

[0036] In the cogeneration power generation system 1 of the first embodiment, the Ts diagram in the theoretical cycle in which there is no fluid loss in the turbine 30 and the compressor 15 is the same as the Ts diagram of the Brayton cycle.

[0037] Between state d and state a, the heat dissipation in the thermal cycle includes the heat quantity q2 of the steam extracted from the extraction pipe 70 and the cooling amount (heat dissipation amount) q3 by the spray water in the cooler 50. In addition, the area enclosed by the state quantities abcd in Figure 2 corresponds to the power generation output of the cogeneration power generation system 1.

[0038] In the cogeneration power generation system 1, if all of the waste heat in the isobaric cooling process from state d to state a can be effectively utilized, the overall theoretical efficiency will theoretically be 100%. Note that this overall theoretical efficiency assumes that there is no heat loss in the system.

[0039] Here, the overall theoretical efficiency is the combined efficiency of the power generation efficiency associated with the amount of power generated and the heat recovery efficiency associated with the effective use of the heat of the combustion gas. The power generation efficiency is the efficiency expressed as a percentage by dividing the amount of power generated by the generator by the calorific value (higher heating value HHV) of the fuel supplied to the combustor 20. The heat recovery efficiency is the efficiency expressed as a percentage by dividing the calorific value of the steam extracted through the extraction pipe 70 by the calorific value (higher heating value HHV) of the fuel supplied to the combustor 20.

[0040] That is, in the cogeneration power generation system 1, it is assumed that the entire amount of heat q2 of the steam extracted from the extraction pipe 70 is used as heat supply. Also, the amount of cooling (amount of heat dissipation) q3 by the spray water in the cooler 50 is entirely used as the amount of heat q3' to evaporate the spray water, and is recovered within the cycle. That is, in theory, the amount of heat discharged outside the system as waste heat in the cogeneration power generation system 1 is "0".

[0041] Furthermore, in the cogeneration power generation system 1, the latent heat of vaporization of steam generated by the combustion of oxygen and hydrogen can be effectively utilized as heat in the extracted steam, so even the higher heating value of the fuel can be utilized. As a result, the cogeneration power generation system 1 can improve the overall theoretical efficiency, which is the combination of power generation efficiency and heat recovery efficiency.

[0042] (Second embodiment) 3 is a system diagram schematically illustrating the configuration of a cogeneration power generation system 2 according to the second embodiment. In the following embodiments, the same components as those in the cogeneration power generation system 1 according to the first embodiment are denoted by the same reference numerals, and redundant explanations will be omitted or simplified.

[0043] 3, the cogeneration power generation system 2 includes a regenerative heat exchanger 80 that heats the steam delivered from the compressor 15 with the steam discharged from the turbine 30. That is, the regenerative heat exchanger 80 exchanges heat between the steam flowing through the steam circulation pipe 60 and the steam at the outlet of the compressor 15.

[0044] 3, the regenerative heat exchanger 80 is provided across a compressed steam introduction pipe 90 that introduces steam from the compressor 15 to the combustor 20 and the steam circulation pipe 60 between the turbine 30 and a connection part 61. The regenerative heat exchanger 80 heats the steam delivered from the compressor 15 with the steam discharged from the turbine 30.

[0045] As in the first embodiment, the extraction pipe 70 is connected to any position in the steam circulation piping 60 that connects the turbine 30 and the compressor 15. Here, an example is shown in which the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the regenerative heat exchanger 80. The extraction pipe 70 may also be connected to the steam circulation piping 60 between the cooler 50 and the compressor 15. In this case, the regenerative heat exchanger 80 is provided across the compressed steam introduction pipe 90 that introduces steam from the compressor 15 to the combustor 20 and the steam circulation piping 60 between the turbine 30 and the cooler 50.

[0046] Next, the heat cycle of the cogeneration power generation system 2 according to the second embodiment will be described.

[0047] FIG. 4 is a Ts diagram that schematically shows the heat cycle of the cogeneration power generation system 2 of the second embodiment.

[0048] As shown in FIG. 4, the heat dissipation during the isobaric cooling process between state d and state a includes the heat dissipation amount q4 from the steam flowing through the steam circulation piping 60 in the regenerative heat exchanger 80, the heat amount q2 of the steam extracted from the extraction pipe 70, and the cooling amount (heat dissipation amount) q3 by the sprayed water in the cooler 50.

[0049] In the isobaric cooling process from state d to state a, first, the steam flowing through the steam circulation pipe 60 releases heat quantity q4 in the regenerative heat exchanger 80, changing from state d to state d'. Then, the steam in state d' undergoes the isobaric cooling process in the steam circulation pipe 60 (cooler 50) and becomes steam in state a.

[0050] Additionally, the entire amount of heat q4 released in the regenerative heat exchanger 80 is used as heat q4' to heat the steam flowing through the compressed steam introduction pipe 90 in the regenerative heat exchanger 80. That is, the steam in state b compressed by the compressor 15 acquires heat q4' in the isobaric heating process in the compressed steam introduction pipe 90 (regenerative heat exchanger 80) and becomes steam in state b'.

[0051] It is assumed that the entire amount of heat q2 of the steam extracted from the extraction pipe 70 is used as heat supply. Also, the entire amount of cooling (heat radiation) q3 by the spray water in the cooler 50 is used as the heat q3' for evaporating the spray water and is recovered within the cycle. That is, in the cogeneration power generation system 2, the amount of heat discharged as exhaust heat to the outside of the system is theoretically "0".

[0052] Here, the steam temperature in each state has the following relationship, for example, as shown in Fig. 4: state d > state b' > state d' > state b. This relationship allows suitable heat exchange to be performed in the regenerative heat exchanger 80.

[0053] By providing the regenerative heat exchanger 80, the steam introduced into the combustor 20 is in state b', so the amount of heat input q1 in the combustor 20 required to heat the inlet of the turbine 30 to state c can be reduced. In other words, by providing the regenerative heat exchanger 80, the total amount of heat generated by the fuel in the combustor 20 can be reduced. Therefore, the power generation efficiency of the cogeneration power generation system 2 can be improved.

[0054] Furthermore, by providing the regenerative heat exchanger 80, it is possible to improve the power generation efficiency while lowering the steam temperature at the inlet of the turbine 30. The reason for this will be explained below.

[0055] If the steam temperature at the inlet of the turbine 30 is lowered and the difference ΔT (temperature difference) between the steam temperature at the inlet of the turbine 30 and the steam temperature at the outlet of the turbine 30 is set to be small, the specific work of the turbine 30 will be reduced. On the other hand, the ratio (pressure ratio) of the steam pressure at the inlet of the turbine 30 to the steam pressure at the outlet of the turbine 30 will be reduced. Therefore, the ratio (pressure ratio) of the steam pressure at the inlet of the compressor 15 to the steam pressure at the outlet of the compressor 15 will also be reduced, and the power required for the compressor 15 will be reduced.

[0056] Furthermore, although the steam temperature at the outlet of the compressor 15 decreases, the difference between the temperature of the steam in state d at the outlet of the turbine 30 and the temperature of the steam in state b at the outlet of the compressor 15 increases. Therefore, the amount of heat exchange between steam in the regenerative heat exchanger 80 increases, and there is almost no decrease in the steam temperature at the inlet of the combustor 20.

[0057] Furthermore, since the temperature of the steam in state c at the inlet of the turbine 30 is also lowered, the amount of heat input q1 in the combustor 20 required to heat the steam to state c at the inlet of the turbine 30 can be reduced.

[0058] In other words, by lowering the steam temperature at the inlet of the turbine 30, the specific work done by the turbine 30 decreases, but the effect of reducing the heat input q1 to the combustor 20 due to the increased heat exchange amount in the regenerative heat exchanger 80 is significant, so power generation efficiency improves.

[0059] Next, the effect of lowering the steam temperature at the inlet of the turbine 30 will be described. When the steam temperature at the inlet of the turbine 30 is set high, the stationary vanes and moving blades are generally configured to be cooled by a cooling medium, from the viewpoint of the heat resistance of the turbine materials. The stationary vanes and moving blades cooled by a cooling medium have a complex cooling structure.

[0060] By lowering the steam temperature at the inlet of the turbine 30, the cooling structure of the stationary vanes and moving blades can be simplified or eliminated. Furthermore, the stationary vanes and moving blades do not require treatments such as thermal barrier coating. Furthermore, the stationary vanes and moving blades can be made of inexpensive materials with reduced high-temperature strength.

[0061] Furthermore, the specific heat C of steam, which is the working fluid, is greater than the specific heat C of combustion gas, which is the working fluid in conventional cogeneration power generation systems. If the difference (temperature difference) between the steam temperature at the inlet and the steam temperature at the outlet of the turbine 30 is ΔT, then the specific work in the turbine 30 is C × ΔT. Therefore, even if the temperature difference ΔT is small, the turbine 30 of this embodiment, which uses steam as the working fluid, can obtain specific work equivalent to that of a conventional turbine, which uses combustion gas as the working fluid.

[0062] That is, when the turbine 30 in the cogeneration power generation system 2 is designed to obtain the same level of specific work as a turbine in a conventional cogeneration power generation system, it becomes possible to design the turbine 30 with a lower steam temperature at the inlet. Furthermore, by providing the regenerative heat exchanger 80, it is possible to suitably improve the power generation efficiency.

[0063] As described above, the cogeneration power generation system 2 can improve the power generation efficiency while lowering the steam temperature at the inlet of the turbine 30. Furthermore, the cogeneration power generation system 2 can also improve the overall theoretical efficiency.

[0064] (Third embodiment) FIG. 5 is a system diagram that schematically shows the configuration of a cogeneration power generation system 3 according to the third embodiment.

[0065] The cogeneration power generation system 3 includes a cooler 100 that cools the steam during the compression process in the compressor 15. The cooler 100 functions as a second cooler. The cogeneration power generation system 3 is configured to include a configuration that cools the steam during the compression process in the compressor 15 in addition to the configuration of the cogeneration power generation system 2 of the second embodiment. Therefore, descriptions that overlap with the description of the cogeneration power generation system 2 of the second embodiment will be omitted or simplified.

[0066] The cooler 100 cools steam by supplying water during the steam compression process in the compressor 15, for example. Water is supplied to the cooler 100 via a water supply pipe 101. The cooler 100 sprays water directly onto the steam during the compression process in the compressor 15. The cooler 100 includes, for example, an injection nozzle that sprays water. The sprayed water is heated by the steam during the compression process and turns into steam. All of the sprayed water turns into steam.

[0067] Here, an example is shown in which compressor 15 includes a first compressor 15a on the low-pressure side and a second compressor 15b on the high-pressure side. Cooler 100 is provided between the outlet of first compressor 15a and the inlet of second compressor 15b. By spraying water onto steam compressed by first compressor 15a, the temperature of the compressed steam is lowered and the sprayed water turns into steam, increasing the steam flow rate.

[0068] The configuration of the compressor 15 is not limited to the two-part structure described above. The compressor 15 may be configured as a single compressor. In this case, the cooler 100 has a configuration capable of spraying water directly onto steam flowing through a predetermined stage of the compressor 15, for example. Even in this case, the temperature of the steam decreases during the steam compression process, and the sprayed water turns into steam, increasing the steam flow rate.

[0069] Furthermore, when the compressor 15 is configured as a single compressor, the cooler 100 may include a steam pipe that returns a portion of the steam extracted from a predetermined stage to a stage downstream of the predetermined stage, and a cooling structure that is provided in the steam pipe and that cools the steam flowing through the steam pipe.

[0070] The cooling structure may be configured to spray water directly onto the steam flowing in the steam pipe, for example, similar to the cooler 100. In this case, during the steam compression process, the temperature of the steam decreases, and the sprayed water turns into steam, increasing the steam flow rate.

[0071] The cooling structure may be, for example, a fin structure that exchanges heat between the steam flowing through the steam pipe and the outside air. In this case, the temperature of the steam decreases during the vapor compression process.

[0072] Next, the heat cycle of the cogeneration power generation system 3 according to the third embodiment will be described.

[0073] FIG. 6 is a Ts diagram that schematically shows the heat cycle of the cogeneration power generation system 3 of the third embodiment.

[0074] 6, the steam in state a isobarically cooled in the steam circulation pipe 60 is compressed by the first compressor 15a to become state e. The steam in state e is then isobarically cooled by the cooler 100 to become state f. The steam in state f is compressed by the second compressor 15b to become state b.

[0075] In the isobaric cooling process from state e to state f, the heat dissipation in the cycle is the cooling amount (heat dissipation) q5 due to the sprayed water in the cooler 100. The entire amount of the cooling amount (heat dissipation) q5 is used as the heat amount q5' to evaporate the sprayed water and is recovered within the cycle.

[0076] In addition, in the cogeneration power generation system 3, in a steady-state operating state, the sum of the amount of steam generated in the cooler 50 and the cooler 100 and the amount of steam generated by oxygen-hydrogen combustion in the combustor 20 is equal to the amount of steam extracted from the extraction pipe 70.

[0077] The other steps of the thermal cycle are as described above.

[0078] In the cogeneration power generation system 3, the steam temperature can be lowered from the temperature of state e to the temperature of state f by cooling the steam during the compression process. When the steam is cooled during the compression process in this way, the power of the compressor 15 is reduced compared to when the steam is not cooled during the compression process.

[0079] Since the power output is the output of the turbine 30 minus the power of the compressor 15, reducing the power of the compressor 15 improves the power generation efficiency of the cogeneration power generation system 3. Furthermore, by cooling the steam midway through the compressor 15, the temperature of the steam at the outlet of the compressor 15 decreases. This increases the amount of heat exchange in the regenerative heat exchanger 80, improving power generation efficiency.

[0080] Furthermore, in the cogeneration power generation system 3, if the cooler 100 is configured to spray water onto steam to evaporate it, the amount of heat discharged outside the system as exhaust heat is theoretically "0".

[0081] As described above, the cogeneration power generation system 3 can improve not only the power generation efficiency but also the overall theoretical efficiency.

[0082] (Fourth embodiment) FIG. 7 is a system diagram that schematically shows the configuration of a cogeneration power generation system 4 according to a fourth embodiment. As the cogeneration power generation system 4, a configuration in which an air extraction pipe 110 is provided in addition to the configuration of the third embodiment is shown as an example. Here, the configuration that differs from the configuration of the third embodiment will be mainly described. Note that the configuration that includes the air extraction pipe 110 may be applied to the cogeneration power generation systems of the other embodiments.

[0083] The cogeneration power generation system 4 includes an extraction pipe 110 that extracts a portion of the steam at the outlet of the compressor 15 or a portion of the steam during the compression process in the compressor 15 and leads the extracted steam as a cooling medium to the turbine 30. The extraction pipe 110 functions as a second extraction pipe.

[0084] 7 illustrates an extraction pipe 110 that extracts a portion of the steam at the outlet of the compressor 15 and leads the extracted steam as a cooling medium to the turbine 30. One end of the extraction pipe 110 is connected to a compressed steam introduction pipe 90 between the compressor 15 and the regenerative heat exchanger 80 at a connection part 92. The other end of the extraction pipe 110 is connected, for example, to an introduction part of the cooling medium in the turbine 30. The temperature of the cooling medium is lower than the temperature of the steam introduced from the combustor 20 to the turbine 30.

[0085] 7 shows an example in which one end of the extraction pipe 110 is connected to the compressed steam introduction pipe 90 at the connection part 92, but the configuration is not limited to this. One end of the extraction pipe 110 may be connected to a predetermined stage of the compressor 15 (the first compressor 15a or the second compressor 15b), for example.

[0086] Alternatively, a plurality of extraction pipes 110 may be provided, and steam may be extracted from different extraction points, and the extracted steam may be introduced into different stages of the turbine 30. The extraction points are determined based on the pressure and temperature of the working fluid in the turbine 30 that supplies the cooling medium.

[0087] According to the cogeneration power generation system 4, by introducing a cooling medium into the turbine 30 through the extraction pipe 110, it is possible to cool components of the turbine 30, such as the rotor blades and the stator blades. This makes it possible to introduce high-temperature steam as a working fluid into the turbine 30. Furthermore, because the cooling medium is steam, the composition of the working fluid does not change even when the cooling medium is mixed with the steam flowing through the flow path of the turbine 30. Furthermore, in the cogeneration power generation system 4, it is possible to obtain the same effects as those in the third embodiment.

[0088] (Fifth embodiment) FIG. 8 is a system diagram that schematically shows the configuration of a cogeneration power generation system 5 according to the fifth embodiment.

[0089] Here, a configuration in which a bypass pipe 120 and a flow rate adjustment valve 121 are added to the configuration of the fourth embodiment is shown as an example of the cogeneration power generation system 5. Here, the configuration that differs from the configuration of the fourth embodiment will be mainly described. Note that the configuration in which the bypass pipe 120 and the flow rate adjustment valve 121 are included may be applied to the cogeneration power generation systems of the other embodiments.

[0090] The cogeneration power generation system 5 includes a bypass pipe 120 and a flow control valve 121 .

[0091] The bypass piping 120 guides a portion of the steam from the outlet of the compressor 15 to the steam circulation piping 60, bypassing the turbine 30. One end of the bypass piping 120 is connected at a connection part 93 to a compressed steam introduction pipe 90 between the compressor 15 (second compressor 15b) and the regenerative heat exchanger 80. The connection part 93 is located, for example, between the compressor 15 (second compressor 15b) and the connection part 92. The other end of the bypass piping 120 is connected at a connection part 62 to the steam circulation piping 60 between the regenerative heat exchanger 80 and the connection part 61.

[0092] The flow rate control valve 121 is provided in the bypass pipe 120 and adjusts the flow rate of steam bypassed to the steam circulation pipe 60. For example, when the flow rate control valve 121 is fully closed, the cycle is the same as that of the fourth embodiment.

[0093] When the flow control valve 121 is opened, a portion of the high-pressure steam discharged from the compressor 15 is introduced into the steam circulation pipe 60 via the bypass pipe 120. This reduces the flow rate of steam introduced into the combustor 20, thereby reducing the amount of heat input q1 in the combustor 20 required to heat the steam to state c at the inlet of the turbine 30.

[0094] Furthermore, the flow rate of steam introduced from the combustor 20 to the turbine 30 decreases due to a decrease in the flow rate of steam introduced into the combustor 20 and a decrease in the heat input q1 at the combustor 20. This reduces the output of the turbine 30, and the power output (power generation amount), which is the turbine output minus the power of the compressor 15, decreases. Although the heat input q1 at the combustor 20 decreases, the contribution of the decrease in power generation amount is large, and power generation efficiency decreases. On the other hand, because the heat quantity q2 of the steam extracted from the extraction pipe 70 remains almost the same, the heat input q1 at the combustor 20 decreases, and the heat recovery efficiency increases.

[0095] By providing the bypass piping 120, it is possible to adjust the ratio between the power generation efficiency and the heat recovery efficiency in the overall theoretical efficiency. Furthermore, in the cogeneration power generation system 5, it is possible to obtain the same effects as those in the fourth embodiment.

[0096] (Other aspects of the fifth embodiment) FIG. 9 is a system diagram that schematically shows another configuration of the cogeneration power generation system 5 according to the fifth embodiment.

[0097] The other configuration of the cogeneration power generation system 5 differs from the configuration of the cogeneration power generation system 5 shown in FIG. 8 in that it includes a pressure regulating valve 91 and a flow rate regulating valve 111.

[0098] 9, the pressure regulating valve 91 is provided in the compressed steam introduction pipe 90 near the inlet of the regenerative heat exchanger 80. The pressure regulating valve 91 is provided on the regenerative heat exchanger 80 side of a connection 92 between the compressed steam introduction pipe 90 and the extraction pipe 110. The pressure regulating valve 91 adjusts the pressure of the steam at the outlet of the compressor 15.

[0099] The flow rate control valve 111 is provided in the extraction pipe 110. The flow rate control valve 111 adjusts the flow rate of steam introduced into the turbine 30 as a cooling medium.

[0100] By providing the pressure regulating valve 91, it is possible to independently adjust the pressure of the steam at the outlet of the compressor 15 and the flow rate of the steam introduced into the bypass pipe 120, facilitating operation control of the compressor 15. Furthermore, by providing the flow rate regulating valve 111, it is possible to appropriately adjust the flow rate of the cooling medium according to the flow rate of the steam introduced from the combustor 20 to the turbine 30.

[0101] (Sixth embodiment) FIG. 10 is a system diagram that schematically shows the configuration of a cogeneration power generation system 6 according to the sixth embodiment.

[0102] Here, a configuration in which a turbine 130 is provided in addition to the configuration of the fifth embodiment (see FIG. 8) is shown as an example of the cogeneration power generation system 6. Here, the configuration that differs from the configuration of the fifth embodiment will be mainly described. Note that the configuration including the turbine 130 may also be applied to the cogeneration power generation systems of the other embodiments.

[0103] As shown in Fig. 10, the cogeneration power generation system 6 includes turbines 130 and 140. In the cogeneration power generation system 6, the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the turbine 30. Here, as shown in Fig. 10, an example is shown in which the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the regenerative heat exchanger 80 at a connection part 61.

[0104] The turbine 130 is interposed in the steam circulation pipe 60 between the connection part 61 and the cooler 50. The turbine 130 is provided in the steam circulation pipe 60 so that its steam inlet is on the connection part 61 side and its steam outlet is on the cooler 50 side. The turbine 130 functions as a second turbine. The generator 140 is coaxially coupled to the turbine 130.

[0105] Steam is introduced into the turbine 130 through the steam circulation pipe 60. The turbine 130 is driven by converting the thermal energy of the steam into rotational energy. As the thermal energy of the steam is converted into rotational energy within the turbine 130, the temperature and pressure of the steam decrease. In the generator 140, which is coaxially coupled to the turbine 130, the rotational energy of the turbine 130 is converted into electrical energy to generate electricity. The steam discharged from the turbine 130 is introduced into the cooler 50 through the steam circulation pipe 60.

[0106] Although an example is shown here in which the rotation shaft of the turbine 130 is configured as a separate shaft from the rotation shaft of the turbine 30, the present invention is not limited to this configuration. For example, the rotation shaft of the turbine 130 may be configured as a coaxial shaft with the rotation shaft of the turbine 30. In this case, the generator 140 may not be provided, and the rotational energy of the turbine 130 may be converted into electrical energy by the generator 40.

[0107] Next, the heat cycle of the cogeneration power generation system 6 according to the sixth embodiment will be described.

[0108] FIG. 11 is a Ts diagram that schematically shows the heat cycle of the cogeneration power generation system 6 according to the sixth embodiment.

[0109] 6, the thermal cycle shown in Fig. 11 adds an expansion process (state d'-state g) in the turbine 130. The steam in state d' is isobarically cooled in the regenerative heat exchanger 80 becomes steam in state g after passing through an expansion process in the turbine 130. The steam in state g becomes steam in state a after passing through an isobaric cooling process in the steam circulation pipe 60 (cooler 50).

[0110] The transitions from state d to state d', from state g to state a, and from state e to state f are all isobaric cooling processes. The heat quantities q4, q3, q3', q5, and q5' in this isobaric cooling process, q4' and q1 in the isobaric heating process, and the heat quantity q2 of the steam extracted from the extraction pipe 70 are as described above.

[0111] Here, the pressure of the steam at the inlet of the turbine 130 is determined based on, for example, the pressure required for the steam extracted from the extraction pipe 70. A lower steam pressure at the outlet of the turbine 130 can increase the output of the turbine 130, but the pressure ratio in the compressor 15 increases, increasing the power required for the compressor 15. Therefore, the pressure of the steam at the outlet of the turbine 130 is determined based on the power generation output of the entire cycle and the design specifications of the compressor 15.

[0112] According to the cogeneration power generation system 6 described above, by providing the turbine 130, the total power generation output of the generator 40 and the generator 140 increases, and therefore the power generation efficiency increases.

[0113] In the cogeneration power generation system 6, if the cooler 100 is configured to spray water onto steam to evaporate it, the amount of heat discharged outside the system as waste heat is theoretically "0". Furthermore, in the cogeneration power generation system 6, in addition to improving power generation efficiency, it is possible to improve overall theoretical efficiency.

[0114] (Seventh embodiment) FIG. 12 is a system diagram that schematically shows the configuration of a cogeneration power generation system 7 according to the seventh embodiment.

[0115] Here, a configuration in which an evaporator 150, a pump 151, and a steam introduction pipe 152 are provided in addition to the configuration of the fifth embodiment (see FIG. 8) is shown as an example of the cogeneration power generation system 7. Here, the configuration that differs from the configuration of the fifth embodiment will be mainly described. Note that the configuration in which the evaporator 150, the pump 151, and the steam introduction pipe 152 are provided may be applied to the cogeneration power generation systems of other embodiments.

[0116] As shown in FIG. 12, the cogeneration power generation system 7 includes an evaporator 150 , a pump 151 , a steam introduction pipe 152 , and a water supply pipe 153 .

[0117] In the cogeneration power generation system 7, the evaporator 150 is provided in the steam circulation piping 60 between the cooler 50 and the turbine 30. Here, as shown in FIG. 12 , an example is shown in which the evaporator 150 is connected to the steam circulation piping 60 between the cooler 50 and the regenerative heat exchanger 80. Note that FIG. 12 also shows an example in which the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the regenerative heat exchanger 80 at a connection part 61. Also, an example is shown in which the evaporator 150 is connected to the steam circulation piping 60 between the cooler 50 and the connection part 61. The evaporator 150 generates steam from water by heat exchange between steam flowing through the steam circulation piping 60 and water supplied from a water supply pipe 153.

[0118] The evaporator 150 includes an evaporation section that includes a heat exchange member such as a fin, which evaporates water supplied from a water supply pipe 153. The water supplied from the water supply pipe 153 becomes steam in the evaporation section. That is, the water flowing through the evaporation section is separated from the steam from the steam circulation pipe 60 that passes through the evaporator 150, and therefore does not mix with the steam.

[0119] The water supply pipe 153 supplies water to the evaporator 150. The pump 151 is provided in the water supply pipe 153, and increases the pressure of the water flowing through the water supply pipe 153 and introduces the water into the evaporator 150.

[0120] The steam introduction pipe 152 is provided between the evaporator 150 and the compressor 15 (second compressor 15b). One end of the steam introduction pipe 152 is connected to a steam outlet of the evaporator 150. The other end of the steam introduction pipe 152 is connected at a connection part 94 to the compressed steam introduction pipe 90 between the outlet of the compressor 15 (second compressor 15b) and a connection part 93. The other end of the steam introduction pipe 152 may be connected to the outlet of the compressor 15 (second compressor 15b).

[0121] Here, the water supplied to the water supply pipe 153 is pressurized by the pump 151 to a pressure equal to or higher than the pressure of the steam at the outlet of the compressor 15 (second compressor 15b), and is supplied to the evaporator 150. The water supplied to the evaporator 150 becomes steam due to the heat of the steam from the steam circulation pipe 60. The steam generated in the evaporator 150 passes through the steam introduction pipe 152 and is introduced into the compressed steam introduction pipe 90 from the connection part 94.

[0122] The steam introduced into the compressed steam introduction pipe 90 flows through the compressed steam introduction pipe 90 toward the regenerative heat exchanger 80 together with the steam discharged from the compressor 15 (second compressor 15b).

[0123] The temperature of the steam flowing through the steam circulation pipe 60 is reduced by heat exchange in the evaporator 150. Then, the steam whose temperature has been reduced is introduced into the cooler 50.

[0124] Next, the heat cycle of the cogeneration power generation system 7 according to the seventh embodiment will be described.

[0125] FIG. 13 is a Ts diagram that schematically shows the heat cycle of the cogeneration power generation system 7 of the seventh embodiment.

[0126] 13, compared to the heat cycle shown in FIG. 6, isobaric cooling (state d'-state h) in the evaporator 150 is added. The steam in state d' that has been isobarically cooled in the regenerative heat exchanger 80 and flows through the steam circulation piping 60 undergoes an isobaric cooling process in the evaporator 150, and becomes steam in state h. In this process, the steam flowing through the steam circulation piping 60 releases heat quantity q6. The steam in state h undergoes an isobaric cooling process in the steam circulation piping 60 (cooler 50), and becomes steam in state a.

[0127] The total amount of heat radiation q6 in the evaporator 150 is utilized as latent heat of vaporization q6' of water supplied to the evaporator 150 via the water supply pipe 153. The steam introduced from the evaporator 150 into the steam inlet pipe 152 is saturated steam. On the other hand, the steam discharged from the compressor 15 (second compressor 15b) is superheated steam. Therefore, this superheated steam is mixed with saturated steam at the connection part 94, thereby causing isobaric cooling. That is, the steam in state b discharged from the compressor 15 (second compressor 15b) is mixed with saturated steam from the steam inlet pipe 152 and undergoes an isobaric cooling process, thereby becoming steam in state i.

[0128] Then, the steam in state i undergoes an isobaric heating process in the regenerative heat exchanger 80 to become steam in state b'.

[0129] Note that the temperature of the steam generated in the evaporator 150 is the saturation temperature at the pressure of the steam at the outlet of the compressor 15, and therefore it is difficult for the evaporator 150 to cool the steam from the steam circulation pipe 60 to a temperature below that saturation temperature. Therefore, in the cogeneration power generation system 7, by providing a cooler 50 on the steam circulation pipe 60 downstream of the evaporator 150, the temperature of the steam flowing through the steam circulation pipe 60 can be further reduced.

[0130] In the Brayton cycle, the power output is obtained by subtracting the power of the compressor from the turbine output. The power of the pump 151 that pressurizes the water is smaller than the power of the compressor 15 that compresses the steam.

[0131] According to the cogeneration power generation system 7, a portion of the amount of water required in the isobaric cooling process is pressurized by the pump 151 to become saturated steam, and this saturated steam can be introduced into the compressed steam introduction pipe 90, bypassing the compressor 15. This reduces the flow rate of steam introduced into the compressor 15. In other words, by providing the evaporator 150, the pump 151, and the steam introduction pipe 152, the steam flowing through the steam circulation pipe 60 can be appropriately isobarically cooled, while the power required by the compressor 15 is reduced and the power output is increased.

[0132] Furthermore, in the cogeneration power generation system 7, the same effects as those in the fifth embodiment can be obtained.

[0133] (Eighth embodiment) FIG. 14 is a system diagram that schematically shows the configuration of a cogeneration power generation system 8 according to the eighth embodiment.

[0134] Here, a configuration in which an extraction pressure regulating valve 160 is provided in addition to the configuration of the fifth embodiment (see FIG. 8) is shown as an example of the cogeneration power generation system 8. Here, configurations that differ from the configuration of the fifth embodiment will be mainly described. Note that the configuration provided with the extraction pressure regulating valve 160 may also be applied to the cogeneration power generation systems of other embodiments.

[0135] As shown in FIG. 14, the cogeneration power generation system 8 includes an extraction pressure regulating valve 160 and a pressure detecting device 161.

[0136] The bleed pressure regulating valve 160 regulates the pressure of steam guided to the bleed pipe 70. The bleed pressure regulating valve 160 is provided in the steam circulation pipe 60 on the compressor 15 side of the connection part 61 at which the bleed pipe 70 is connected to the steam circulation pipe 60. Fig. 14 shows an example in which the bleed pipe 70 is connected to the steam circulation pipe 60 between the cooler 50 and the regenerative heat exchanger 80. Also shown is an example in which the bleed pressure regulating valve 160 is provided in the steam circulation pipe 60 between the cooler 50 and the connection part 61. In this case, the bleed pressure regulating valve 160 may be provided in the steam circulation pipe 60 between the cooler 50 and the compressor 15, for example.

[0137] Here, for example, when the extraction pipe 70 is connected to the steam circulation piping 60 between the cooler 50 and the compressor 15 at the connection part 61, the extraction pressure control valve 160 is provided in the steam circulation piping 60 between the connection part 61 and the compressor 15.

[0138] The pressure detection device 161 detects the pressure of the steam flowing through the extraction pipe 70. The pressure detection device 161 is provided in the extraction pipe 70.

[0139] The opening of the bleed pressure regulating valve 160 is adjusted so that the pressure of the steam flowing through the bleed pipe 70 becomes a predetermined pressure. When the steam pressure in the bleed pipe 70 drops below the predetermined pressure, the opening of the bleed pressure regulating valve 160 is decreased to increase the pressure in the bleed pipe 70. When the steam pressure in the bleed pipe 70 rises above the predetermined pressure, the opening of the bleed pressure regulating valve 160 is increased to decrease the pressure in the bleed pipe 70.

[0140] The opening of the bleed pressure regulating valve 160 may be adjusted and controlled by a control device (not shown) based on a detection signal from the pressure detecting device 161, for example.

[0141] According to the cogeneration power generation system 8, by providing the extraction pressure regulating valve 160, the pressure of the steam extracted from the extraction pipe 70 can be maintained at a predetermined pressure. Furthermore, by providing the extraction pressure regulating valve 160, the pressure of the steam at the outlet of the turbine 30 can be maintained constant. This makes it possible to suppress fluctuations in turbine output, enabling stable operation of the cogeneration power generation system 8.

[0142] Furthermore, in the cogeneration power generation system 8, the same effects as those in the fifth embodiment can be obtained.

[0143] (Ninth embodiment) FIG. 15 is a system diagram that schematically shows the configuration of a cogeneration power generation system 9 according to the ninth embodiment.

[0144] The cogeneration power generation system 9 differs from the configuration of the fourth embodiment (see FIG. 7) in the connection of the air extraction pipe. Here, the configuration that differs from the configuration of the fourth embodiment will be mainly described. Note that the configuration of the air extraction pipe of this embodiment may be applied to the cogeneration power generation systems of other embodiments.

[0145] 15, in the cogeneration power generation system 9, the extraction pipe 70 is connected at a connection part 95 to the compressed steam introduction pipe 90 between the compressor 15 (second compressor 15b) and a connection part 92. As described above, in the fourth embodiment, the extraction pipe 70 is connected to the steam circulation piping 60 at the connection part 61, but in the ninth embodiment, the extraction pipe 70 is connected to the compressed steam introduction pipe 90 at the connection part 95 instead of the connection part 61. The connection part 95 functions as a second connection part.

[0146] By connecting the extraction pipe 70 to the compressed steam introduction pipe 90 at the connection part 95, it is possible to extract high-pressure steam derived from the compressor 15 (second compressor 15b). For example, the required temperature and pressure of the extracted steam differ depending on the application in which the extracted steam is used. When high-pressure steam is required, the connection part 95 of the extraction pipe 70 in the cogeneration power generation system 9 is suitable.

[0147] The connection part of the extraction pipe 70 may be changed as appropriate depending on the required steam pressure. For example, depending on the required steam pressure, the extraction pipe 70 may be connected to a location in the compressor 15 where steam from a predetermined stage can be extracted.

[0148] According to the cogeneration power generation system 9, by supplying high-pressure steam through the extraction pipe 70, there is no need for a device for further pressurizing the steam after extraction. Furthermore, the cogeneration power generation system 9 can achieve the same effects as those in the fourth embodiment.

[0149] (Tenth embodiment) FIG. 16 is a system diagram that schematically shows the configuration of a cogeneration power generation system 10 according to the tenth embodiment.

[0150] Here, a configuration in which a turbine 170 is provided in addition to the configuration of the fifth embodiment (see FIG. 8) is shown as an example of the cogeneration power generation system 10. Here, the configuration that differs from the configuration of the fifth embodiment will be mainly described. Note that the configuration including the turbine 170 may also be applied to the cogeneration power generation systems of other embodiments.

[0151] As shown in FIG. 16, the cogeneration power generation system 10 includes a turbine 170, a generator 171, and a steam supply pipe 172.

[0152] One end of the steam supply pipe 172 is connected to the extraction pipe 70 at a connection part 71. The other end of the steam supply pipe 172 is connected to the inlet of the turbine 170.

[0153] The turbine 170 is driven by steam introduced through the extraction pipe 70 and the steam supply pipe 172. The turbine 170 functions as a third turbine. The generator 171 is coaxially coupled to the turbine 170.

[0154] The steam supply pipe 172 is provided with a flow rate control valve 173 that adjusts the flow rate of steam introduced into the turbine 170. The extraction pipe 70 is provided with a flow rate control valve 72 on the heat utilization equipment side of the connection part 71 that adjusts the flow rate of the extracted steam.

[0155] Here, steam is introduced into the turbine 170 via the extraction pipe 70 and the steam supply pipe 172. The turbine 170 is driven by converting the thermal energy of the steam into rotational energy. As the thermal energy of the steam is converted into rotational energy within the turbine 170, the temperature and pressure of the steam decrease. In the generator 171, which is coaxially coupled to the turbine 170, the rotational energy of the turbine 170 is converted into electrical energy to generate electricity.

[0156] The steam discharged from the turbine 170 is supplied to a condenser (not shown). The water condensed in the condenser may be pressurized by a pump (not shown) and supplied to the water supply pipe 51.

[0157] Here, when the flow rate control valve 72 is fully opened and the steam supply pipe 172 is fully closed, the configuration is the same as that of the fifth embodiment. By adjusting the opening degrees of the flow rate control valve 72 and the flow rate control valve 173, the flow rate of steam extracted to the heat utilization facility side and the flow rate of steam introduced into the turbine 170 can be adjusted.

[0158] For example, decreasing the opening of flow rate adjustment valve 72 and increasing the opening of flow rate adjustment valve 173 increases the proportion of power generation output and decreases the proportion of heat output. On the other hand, increasing the opening of flow rate adjustment valve 72 and decreasing the opening of flow rate adjustment valve 173 decreases the proportion of power generation output and increases the proportion of heat output.

[0159] Although an example in which one end of the steam supply pipe 172 is connected to the steam extraction pipe 70 at the connection part 71 has been shown here, the present invention is not limited to this configuration. For example, one end of the steam supply pipe 172 may be connected to the steam circulation pipe 60 between the connection part 61 and the connection part 62.

[0160] According to the cogeneration power generation system 10, the ratio of power output to heat output to the heat utilization facility can be adjusted as desired by adjusting the opening of the flow control valve 173 and the flow control valve 72. Therefore, the cogeneration power generation system 10 can respond to fluctuations in the power generation demand and heat demand required of the cogeneration power generation system.

[0161] (Eleventh embodiment) FIG. 17 is a system diagram that schematically shows the configuration of a cogeneration power generation system 11 according to the eleventh embodiment.

[0162] Here, a configuration in which an oxygen production device 180 and a preheater 181 are added to the configuration of the fifth embodiment (see FIG. 8) is shown as an example of the cogeneration power generation system 11. Here, the configuration that differs from the configuration of the fifth embodiment will be mainly described. Note that the configuration including the oxygen production device 180 and the preheater 181 may be applied to the cogeneration power generation systems of the other embodiments.

[0163] As shown in FIG. 17, the cogeneration power generation system 11 includes an oxygen production device 180, a preheater 181, and an exhaust gas discharge pipe 182.

[0164] The oxygen production device 180 produces oxygen to be supplied to the combustor 20. The oxygen supply pipe 22 is connected to the oxygen production device 180 and supplies the oxygen produced in the oxygen production device 180 to the combustor 20. In addition, the oxygen production device 180 is connected to an exhaust gas discharge pipe 182 that discharges exhaust gas generated during oxygen production.

[0165] The preheater 181 preheats the water to be supplied to the cooler 50 by the exhaust gas introduced from the oxygen production device 180 via the exhaust gas discharge pipe 182. That is, in the preheater 181, heat exchange is performed between the water flowing through the water supply pipe 51 and the exhaust gas flowing through the exhaust gas discharge pipe 182.

[0166] The water supply pipe 51 passes through the preheater 181. The water supply pipe 51 inside the preheater 181 is equipped with a heat exchange member, such as a fin, that performs heat exchange. The exhaust gas flowing through the exhaust gas discharge pipe 182 is introduced into the preheater 181. Then, inside the preheater 181, heat exchange occurs between the water and the exhaust gas via the heat exchange member of the water supply pipe 51. Therefore, the water and the exhaust gas do not mix.

[0167] In the cogeneration power generation system 11 having the above-described configuration, oxygen produced in the oxygen production device 180 is supplied to the combustor 20 via the oxygen supply pipe 22. Exhaust gas generated during oxygen production in the oxygen production device 180 is introduced into the preheater 181 via the exhaust gas discharge pipe 182. The exhaust gas introduced into the preheater 181 heats the water flowing through the water supply pipe 51 by heat exchange.

[0168] The water heated in the preheater 181 is supplied to the cooler 50 via the water supply pipe 51. The exhaust gas that has heated the water in the preheater 181 is discharged from the preheater 181 to the outside via the exhaust gas discharge pipe 182.

[0169] Although an example has been shown here in which the water supplied to the cooler 50 is heated by the exhaust gas generated during oxygen production, the present invention is not limited to this. For example, the fuel supplied to the combustor 20 may be preheated by the exhaust gas generated during oxygen production. In this case, the preheater 181 is disposed in the hydrogen supply pipe 21 and performs heat exchange between the hydrogen flowing through the hydrogen supply pipe 21 and the exhaust gas flowing through the exhaust gas discharge pipe 182, similar to the case in which the water flowing through the water supply pipe 51 described above is heated.

[0170] According to the cogeneration power generation system 11, the cycle efficiency can be further improved by effectively utilizing the exhaust heat from the oxygen production device 180 as an external heat source. Furthermore, the cogeneration power generation system 11 can achieve the same effects as those in the fifth embodiment.

[0171] According to the embodiment described above, it is possible to improve the overall theoretical efficiency, which is a combination of the power generation efficiency associated with the amount of power generated and the heat recovery efficiency associated with the effective use of the heat quantity of the combustion gas.

[0172] Although several embodiments of the present invention have been described, these embodiments are presented as examples and are not intended to limit the scope of the invention. These novel embodiments can be embodied in various other forms, and various omissions, substitutions, and modifications can be made without departing from the spirit of the invention. These embodiments and their modifications are included within the scope and spirit of the invention, and are also included in the scope of the invention and its equivalents as defined in the claims. [Explanation of symbols]

[0173] 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 11... Cogeneration power generation system, 15... Compressor, 15a... First compressor, 15b... Second compressor, 20... Combustor, 21... Hydrogen supply pipe, 22... Oxygen supply pipe, 30, 130, 170... Turbine, 40, 140, 171... Generator, 50... Cooler, 51, 153... Water supply pipe, 60... Steam circulation pipe, 61, 62, 71, 92, 93, 94, 95... Connection, 7 0...extraction pipe, 72, 111, 121, 173...flow control valve, 80...regenerative heat exchanger, 90...compressed steam inlet pipe, 91...pressure control valve, 100...cooler, 101...water supply pipe, 110...extraction pipe, 120...bypass piping, 150...evaporator, 151...pump, 152...steam inlet pipe, 160...extraction pressure control valve, 161...pressure detection device, 172...steam supply pipe, 180...oxygen production device, 181...preheater, 182...exhaust gas discharge pipe.

Claims

1. a compressor for compressing the vapor; a combustor that burns oxygen and hydrogen to generate steam and heats the steam introduced from the compressor; a first turbine into which steam discharged from the combustor is introduced; a steam circulation pipe that introduces steam discharged from the first turbine into the compressor; a first cooler that supplies water into the steam circulation pipe to cool the steam; a first extraction pipe connected to the steam circulation pipe at a first connection portion and extracting a portion of the steam; A cogeneration power generation system comprising:

2. 2. The cogeneration power generation system according to claim 1, further comprising a regenerative heat exchanger for heating the steam discharged from the compressor with the steam discharged from the first turbine.

3. 2. The cogeneration power generation system according to claim 1, further comprising a second cooler for cooling the steam during the compression process in the compressor.

4. 2. The cogeneration power generation system according to claim 1, further comprising a second extraction pipe for extracting a portion of the steam at the outlet of the compressor or a portion of the steam during the compression process in the compressor and directing the extracted steam to the first turbine as a cooling medium.

5. a bypass pipe that guides a portion of the steam from an outlet of the compressor to the steam circulation pipe; a flow rate control valve that is provided in the bypass piping and that adjusts the flow rate of steam that is led to the bypass piping; 2. The cogeneration power generation system according to claim 1, further comprising:

6. a second turbine interposed in the steam circulation piping between the first connection portion and the first cooler; 2. The cogeneration power generation system according to claim 1, wherein the first connection portion is located between the first cooler and the first turbine.

7. A pump that pressurizes the water; an evaporator provided in the steam circulation pipe between the first cooler and the first turbine, which generates steam by performing heat exchange between steam flowing through the steam circulation pipe and water pressurized by the pump; a steam introduction pipe for introducing the steam generated in the evaporator to an outlet of the compressor; 2. The cogeneration power generation system according to claim 1, further comprising:

8. 2. The cogeneration power generation system according to claim 1, further comprising a pressure regulating valve provided in the steam circulation piping on the compressor side of the first connection portion, for regulating the pressure of the steam guided to the first extraction pipe.

9. 2. The cogeneration power generation system according to claim 1, wherein the first extraction pipe is connected to an outlet of the compressor or a predetermined stage in the compressor at a second connection portion instead of the first connection portion.

10. 2. The cogeneration power generation system according to claim 1, further comprising a third turbine to which steam extracted from the first extraction pipe or the steam circulation pipe is introduced.

11. an oxygen production device that produces oxygen to be supplied to the combustor; a preheater that preheats water to be supplied to the first cooler or fuel to be supplied to the combustor by using exhaust gas discharged from the oxygen production device; 2. The cogeneration power generation system according to claim 1, further comprising:

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