Geothermal power generation system using pressure exchanger

Abstract

The system includes a pressure exchanger (PX) configured to receive a first fluid through a first inlet and a second fluid through a second inlet. The PX exchanges pressure between the first fluid and the second fluid and provides the first fluid to a first outlet and the second fluid to a second outlet. The system further includes a heat exchanger that exchanges corresponding thermal energy between the first fluid and the second fluid. The system further includes a turbine configured to receive the second fluid output from the first heat exchanger and convert the corresponding energy of the second fluid into rotational kinetic energy.

Description

[Technical field]

[0001] The present disclosure relates to geothermal power generation systems, and more particularly, to geothermal power generation systems using pressure exchangers. [Background technology]

[0002] The system uses fluids at different pressures. Pumps and / or compressors may be used to increase the pressure of the fluids used by the system.

[0003] The present disclosure is illustrated by way of example and not by way of limitation in the figures of the accompanying drawings. [Brief description of the drawings]

[0004] [Figure 1A] 1 illustrates a schematic diagram of a fluid processing system including a hydraulic energy transfer system, according to certain embodiments. [Figure 1B] 1 illustrates a schematic diagram of a fluid processing system including a hydraulic energy transfer system, according to certain embodiments. [Figure 2A] FIG. 2 is an exploded perspective view of a pressure exchanger (PX) according to a particular embodiment. [Figure 2B] FIG. 2 is an exploded perspective view of a pressure exchanger (PX) according to a particular embodiment. [Figure 2C] FIG. 2 is an exploded perspective view of a pressure exchanger (PX) according to a particular embodiment. [Figure 2D] FIG. 2 is an exploded perspective view of a pressure exchanger (PX) according to a particular embodiment. [Figure 2E] FIG. 2 is an exploded perspective view of a pressure exchanger (PX) according to a particular embodiment. [Figure 3A] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 3B] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 3C] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 3D] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 4] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 5A] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 5B] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 6] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 7] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 8] 1 is a schematic diagram of a geothermal power generation system including a PX, according to certain embodiments. [Figure 9] 1 is a flow diagram illustrating an exemplary method for controlling a geothermal power generation system, in accordance with certain embodiments. [Figure 10] FIG. 1 is a block diagram illustrating a computer system in accordance with certain embodiments. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0005] SUMMARY OF THE DISCLOSURE The embodiments described herein relate to geothermal power generation systems (eg, geothermal fluid processing systems, energy generation systems including pressure exchangers).

[0006] Systems may use fluids at different pressures. Such systems may include hydraulic fracturing (e.g., fracking or fracing) systems, desalination systems, refrigeration systems, heat pump systems, energy generation systems, mud pump systems, slurry pump systems, industrial fluid systems, waste systems, fluid transport systems, geothermal power systems, soil heat source systems, etc. Pumps or compressors may be used to increase the pressure of the fluids used by the systems.

[0007] Traditionally, geothermal systems (e.g., soil heat sources, geothermal heat pumps, soil-source heat pumps) exchange heat between the soil and the rest of the system. Traditional geothermal systems include geothermal heat pumps (e.g., soil-source heat pumps), which are heating / cooling systems for buildings that use a type of heat pump that transfers heat to or from the soil and that takes advantage of the relatively constant temperature of the earth throughout the seasons. Traditional geothermal systems include systems that use heated fluid (e.g., hot water) from a geothermal source (e.g., from the Earth's interior, from a heated part of the Earth, from a hydrothermal reservoir via a production well) to heat and / or evaporate the fluid into steam. This steam can be used to spin a turbine, which can be used to generate electricity. Traditional geothermal systems reduce the pressure of the high-temperature, high-pressure geothermal fluid from the production well to a low pressure before introducing the high-temperature geothermal fluid into a heat exchanger. In the heat exchanger, heat is exchanged with a working fluid (e.g., water / steam) that is used in the turbine. The geothermal fluid is then reinjected into the soil (e.g., via an injection well into an aquifer). Conventional geothermal power generation systems have low efficiency because the geothermal fluid received from the production well is at a low temperature relative to the operating temperature of the steam turbine system driven by combustion (e.g., a coal-fired steam turbine). For example, the Carnot efficiency (η max =1-T L / T H ), the temperature of the high-temperature heat source (T H ) is low, the maximum efficiency remains low. Because the geothermal fluid received from the production well of a geothermal power generation system is at high pressure, it can be used to increase the efficiency of the system despite the relatively low temperature of the hot geothermal fluid.

[0008] The disclosed systems, devices, and methods provide a fluid processing system (e.g., for geothermal power generation, etc.) that includes a pressure exchanger (PX). In some embodiments, the system (e.g., fluid processing system, heat transfer system, geothermal power generation system) is configured to transfer a first fluid (e.g., a high pressure geothermal fluid, such as water and / or brine) and a second fluid (e.g., a low pressure portion of the working fluid of a turbine cycle, low pressure CO 2 , supercritical CO 2 In some embodiments, the PX may receive a first fluid at a first pressure via a first inlet (e.g., a high pressure inlet) and a second fluid at a second pressure via a second inlet (e.g., a low pressure inlet). The PX may exchange pressure between the first and second fluids. The first fluid may exit the PX at a third pressure via a first outlet (e.g., a low pressure outlet), and the second fluid may exit the PX at a fourth pressure via a second outlet (e.g., a high pressure outlet). The first pressure may be higher than the second pressure, and the third pressure may be lower than the fourth pressure.

[0009] In some embodiments, the system includes a heat exchanger (e.g., a primary heat exchanger) configured to exchange corresponding thermal energy between the first fluid and the second fluid. In some embodiments, the first fluid transfers (e.g., loses) heat to the second fluid (e.g., via the heat exchanger). In some embodiments, the heat exchanger is disposed downstream of the PX on the first fluid flow path and downstream of the PX on the second fluid flow path. In some embodiments, the heat exchanger is disposed upstream of the PX on the first fluid flow path. The second fluid may enter the heat exchanger at a high pressure (e.g., near a fourth pressure at which the second fluid may exit the PX via a high-pressure outlet of the PX) and may exit the heat exchanger with an elevated temperature. In some embodiments, the second fluid may be in a supercritical state (e.g., supercritical CO 2 ) the second fluid is heated in the heat exchanger.

[0010] In some embodiments, the system includes a turbine. The turbine may receive the second fluid (e.g., at elevated pressure and temperature) from the heat exchanger. The turbine may convert the corresponding energy (e.g., kinetic energy, pressure, thermal energy) of the second fluid into rotational energy (e.g., rotational kinetic energy). In some embodiments, the turbine drives a generator that may be used to generate electricity. The second fluid with reduced pressure and temperature may exit the turbine and flow toward a second inlet of the PX where it may be recompressed and sent to the heat exchanger again to complete the turbine cycle. In some embodiments, the turbine converts the supercritical CO 2 The apparatus is configured to receive and / or supply a supercritical fluid, such as a

[0011] The disclosed systems, devices, and methods have advantages over conventional solutions. The disclosed geothermal power generation systems may have increased efficiency compared to conventional systems. For example, the systems described herein use high temperature and pressure of geothermal fluid received from a geothermal source (e.g., underground) to increase the temperature and pressure of a working fluid to drive a turbine. In some embodiments, by using PX, the systems described herein reduce the energy consumed to increase the pressure of the working fluid to a supercritical state to drive the turbine. In some embodiments, the disclosure provides reduced wear of components (e.g., pumps, compressors) compared to conventional systems because the pumps and compressors are operated at a higher efficiency (e.g., the PX performs at least a portion of the pressure increase of the second fluid) compared to conventional systems. This also increases the reliability, reduces maintenance, extends the useful life of components, reduces system downtime, and increases production (e.g., energy production) of the systems described herein.

[0012] Although some embodiments of the present disclosure are described in relation to pressure exchangers, energy recovery devices, and hydraulic energy transmission systems, the present disclosure is also applicable to other systems and devices (e.g., non-isostatic pressure exchangers, rotating elements that are not pressure exchangers, non-rotary pressure exchangers, and systems that do not include a pressure exchanger).

[0013] Although some embodiments of the present disclosure are described in the context of pressure exchange between fluids used in fracking, desalination, geothermal power, heat pump, and / or refrigeration systems, the present disclosure is applicable to other types of systems. Fluids may refer to liquids, gases, transcritical fluids, supercritical fluids, subcritical fluids, and / or combinations thereof.

[0014] Although some embodiments of the present disclosure are described in connection with receiving high temperature, high pressure fluids (e.g., brine and / or water) from soil (e.g., hydrothermal formations), the present disclosure may also receive other types of fluids (e.g., low temperature, low pressure) from soil (e.g., below ground level).

[0015] Although some embodiments of the present disclosure are described in connection with receiving fluids from high temperature sources below the earth's surface (e.g., hydrothermal formations), the present disclosure may also receive fluids from other below-earth-surface sources (e.g., ambient ground temperatures).

[0016] FIG. 1A shows a schematic diagram of a fluid treatment system 100A including a hydraulic energy transfer system 110, in accordance with certain embodiments.

[0017] In some embodiments, the hydraulic energy transfer system 110 includes a pressure exchanger (e.g., PX). The hydraulic energy transfer system 110 (e.g., PX) receives a low pressure (LP) in fluid 120 from an LPin system 122 (e.g., via a low pressure inlet). The hydraulic energy transfer system 110 also receives a high pressure (HP) in fluid 130 from an HPin system 132 (e.g., via a high pressure inlet). In some embodiments, the HPin system 132 includes a source of high temperature, high pressure geothermal fluid (e.g., hydrothermal reservoir, geothermal production well). The hydraulic energy transfer system 110 (e.g., PX) exchanges pressure between the HPin fluid 130 and the LPin fluid 120 and provides an LPout fluid 140 (e.g., via a low pressure outlet) to the LPout system 142 and an HPout fluid 150 (e.g., via a high pressure outlet) to the HPout system 152. In some embodiments, the HPout fluid system 152 includes a turbine (e.g., as part of a power generation cycle) to recover energy from the HPout fluid 150. The controller 180 may regulate the flow rates of the HPin fluid 130 and the LPout fluid.

[0018] In some embodiments, the hydraulic energy transfer system 110 includes a PX that exchanges pressure between the HPin fluid 130 and the LPin fluid 120. In some embodiments, the PX is substantially or partially isobaric (e.g., an isobaric pressure exchanger (IPX)). The PX may be a device that transfers fluid pressure between the HPin fluid 130 and the LPin fluid 120 (e.g., without utilizing centrifugal techniques) with an efficiency (e.g., pressure transfer efficiency, substantially isobaric) of about 50%, 60%, 70%, 80%, 90%, or greater. High pressure (e.g., HPin fluid 130, HPout fluid 150) refers to a pressure that is higher than low pressure (e.g., LPin fluid 120, LPout fluid 140). The LPin fluid 120 of the PX may be pressurized and leave the PX at a high pressure (e.g., HPout fluid 150 at a pressure higher than that of the LPin fluid 120), and the HPin fluid 130 may be depressurized and leave the PX at a low pressure (e.g., LPout fluid 140 at a pressure lower than that of the HPin fluid 130). The PX may operate with the HPin fluid 130 exerting a direct force to pressurize the LPin fluid 120 with or without a fluid separator between the fluids. Examples of fluid separators that may be used in the PX include, but are not limited to, pistons, bladders, diaphragms, and the like. In some embodiments, the PX may be a rotary device. Rotary PXs, such as those manufactured by Energy Recovery Inc. of San Leandro, Calif., may not have any separate valves since effective valving is achieved within the device via the relative motion of the rotor to the end cover. Rotary PXs may be designed to operate with internal pistons to separate the fluids and transmit pressure with relatively little mixing of the inlet fluid streams. A reciprocating PX may have a piston in a cylinder that moves back and forth to transfer pressure between fluid streams. Any PX or multiple PXs may be used in the present disclosure, including, but not limited to, a rotary PX, a reciprocating PX, or any combination thereof. Additionally, the PX may be located on a skid separate from other components of the fluid treatment system 100 (e.g., if the PX is being added to an existing fluid treatment system).For example, the PX may be fixed to a structure that can be moved from one location to another. The PX may be tied to a system installed on-site (e.g., the system's pipes). The structure to which the PX is fixed may be referred to as a "skid."

[0019] In some embodiments, a motor 160 is coupled to the hydraulic energy transfer system 110 (e.g., to PX). In some embodiments, the motor 160 controls the speed (e.g., rotational speed, angular velocity) of a rotor of the hydraulic energy transfer system 110 (e.g., to increase the pressure of the HPout fluid 150, or decrease the pressure of the HPout fluid 150). In some embodiments, the motor 160 generates energy (e.g., functions as a generator) based on pressure exchanges in the hydraulic energy transfer system 110.

[0020] The hydraulic energy transfer system 110 may include a hydraulic pressure exchanger, such as a hydraulic turbocharger or a rotary PX. The PX may include one or more (e.g., 1-100) chambers that facilitate pressure transfer between a first fluid and a second fluid (e.g., gas, liquid, multiphase fluid). In some embodiments, the PX may transfer pressure between a first fluid (e.g., a pressure exchange fluid, such as a proppant-free or substantially proppant-free fluid, a low viscosity fluid, a fluid having a certain chemical amount below a threshold, a non-caustic fluid, a non-acidic fluid, etc.) and a second fluid that may have a high viscosity (e.g., very viscous), contain a certain chemical amount above a threshold (e.g., a caustic fluid, an acidic fluid), and / or contain solid particles (e.g., geothermal fluids, fracking fluids containing sand, proppant, powder, debris, ceramics, etc.).

[0021] Fluid process system 100A may further include one or more sensors to provide sensor data (e.g., flow rate data, pressure data, velocity data) associated with the fluid in fluid process system 100A. Controller 180 may control one or more flow rates in fluid process system 100A based on the sensor data. In some embodiments, controller 180 actuates one or more flow valves based on the received sensor data. In some embodiments, controller 180 may implement the method of FIG. 9.

[0022] One or more components of hydraulic energy transfer system 110 may be used in different types of systems, such as geothermal power systems, fracking systems, desalination systems, refrigeration and heat pump systems, slurry pump systems, industrial fluid systems, waste fluid systems, fluid transport systems, heat transport systems, etc.

[0023] Figure IB illustrates a schematic diagram of a fluid treatment system 100B including a hydraulic energy transfer system 110, according to certain embodiments. Fluid treatment system 100B may be a geothermal power generation system. In some embodiments, fluid treatment system 100B may have more components, fewer components, the same routing, different routing, and / or the like than those shown in Figure IB. Some of the features in Figure IB that have similar reference numbers as those in Figure 1A may have similar properties, functions, and / or structures as those in Figure 1A.

[0024] The HPin fluid 130 and the LPout fluid 140 can be geothermal fluids (e.g., particle-containing fluids, hot water, high temperature geothermal brine). The LPin fluid 120 and the HPout fluid 150 can be process fluids (e.g., proppant-free fluids, water, filtered fluids, CO 2 , supercritical CO 2 , hydrofluorocarbons such as R134a, R245fa, etc., hydrocarbons such as isobutene, pentane, propane, etc.

[0025] LPin system 122 may include one or more low pressure fluid pumps and / or compressors for supplying LPin fluid 120 to hydraulic energy transfer system 110 (e.g., PX). HPin system 132 may include a hydrothermal reservoir 134 for supplying HPin fluid 130 to hydraulic energy transfer system 110. In some embodiments, HPin fluid 130 is received by hydraulic energy transfer system 110 via a production well in fluid communication with hydrothermal reservoir 134. Controller 180 may control one or more components of fluid treatment system 100B.

[0026] The hydraulic energy transfer system 110 is connected to a LPin fluid 120 (e.g., low pressure process fluid, low pressure CO 2 ) and the HPin fluid 130 (e.g., high pressure geothermal fluid, high pressure hot water), and the HPout fluid 150 (e.g., high pressure process fluid, high pressure CO 2 ) to the HPout system 152 and supplies the LPout fluid 140 (e.g., low pressure geothermal fluid, low pressure hot water) to the LPout system 142. In some embodiments, the HPout system 152 includes a turbine 128 that receives the HPout fluid 150. The turbine 128 may convert thermal energy of the HPout fluid 150 into kinetic energy and supply the fluid to the LPin system 122. The turbine 128 may be mechanically coupled to a generator to produce electricity. In some embodiments, the fluid from the turbine 128 is cooled in a gas cooler 118 of the LPin system 122 to form the LPin fluid 120. In some embodiments, the LPout fluid 140 is supplied to a heat exchanger to exchange thermal energy with the HPout fluid 150 (e.g., exchange heat, supply heat, etc.). The heated HP fluid 150 may be supplied to the turbine 128. The cooled LPout fluid 140 may be supplied to the HPin system 132 by reinjection into the hydrothermal reservoir 134 (eg, via an injector well).

[0027] The fluid treatment system 100B may further include one or more sensors configured to provide sensor data associated with the fluid. The one or more flow valves may control the flow rate of the fluid based on the sensor data received from the one or more sensors. In some embodiments, the controller 180 actuates the one or more flow valves (not shown) based on the received sensor data.

[0028] 2A-E are exploded perspective views of a rotary PX 40 (e.g., a rotary pressure exchanger, a rotary liquid piston compressor (LPC)) according to certain embodiments. Some of the features in one or more of Figures 2A-E may have similar characteristics, functions, and / or structures as those in one or more of Figures 1A-D.

[0029] The PX 40 is configured to transfer pressure and / or work between a first fluid (e.g., geothermal fluid, water and / or brine, slurry fluid, caustic fluid, acid fluid, fracking fluid, superheated carbon dioxide gas, HPin fluid 130) and a second fluid (e.g., process fluid, particle-free fluid, non-caustic fluid, non-acid fluid, proppant-free fluid, or supercritical carbon dioxide, LPin fluid 120) with minimal fluid mixing. The rotary PX 40 may include a generally cylindrical body portion 42 including a sleeve 44 (e.g., rotor sleeve) and a rotor 46. The rotary PX 40 may also include two end caps 48 and 50 including manifolds 52 and 54, respectively. The manifold 52 includes respective inlet and outlet ports 56 and 58, and the manifold 54 includes respective inlet and outlet ports 60 and 62. In operation, such inlet ports 56, 60 allow a first fluid and a second fluid to enter and exchange pressure with the rotary PX 40, while the outlet ports 58, 62 allow the first fluid and the second fluid to exit the rotary PX 40. In operation, the inlet port 56 may be routed to receive a first fluid at high pressure (e.g., HPin fluid 130) and, after exchanging pressure, the outlet port 58 may be routed to allow a first fluid at low pressure (e.g., LPout fluid 140) to exit the rotary PX 40. Similarly, the inlet port 60 may be routed to receive a second fluid at low pressure (e.g., low pressure slurry fluid, LPin fluid 120) and the outlet port 62 may be routed to allow a second fluid at high pressure (e.g., high pressure slurry fluid, HPout fluid 150) to exit the rotary PX 40. End caps 48 and 50 are disposed within respective manifolds 52 and 54 and include respective end covers 64 and 66 (eg, end plates) that provide fluid-sealing contact with rotor 46 .

[0030] One or more components of PX 40, such as rotor 46, end cover 64, and / or end cover 66, may be constructed from a wear-resistant material (e.g., carbide, cemented carbide, silicon carbide, tungsten carbide, etc.) having a hardness greater than a predetermined threshold (e.g., a Vickers hardness number of at least 1000, 1250, 1500, 1750, 2000, 2250, or greater). For example, tungsten carbide may be more durable and have improved wear resistance to abrasive fluids compared to other materials, such as alumina ceramic. Additionally, in some embodiments, one or more components of PX 40, such as rotor 46, end cover 64, end cover 66, and / or other sealing surfaces of PX 40, may include inserts. In some embodiments, the insert may be constructed from one or more wear-resistant materials (e.g., carbides, cemented carbides, silicon carbide, tungsten carbide, etc.) having a hardness greater than a predetermined threshold (e.g., a Vickers hardness number of at least 1000, 1250, 1500, 1750, 2000, 2250, or greater) to enhance wear resistance.

[0031] The rotor 46 may be cylindrical and disposed within the sleeve 44, which allows the rotor 46 to rotate about an axis 68. The rotor 46 may have a number of channels 70 (e.g., ducts, rotor ducts) extending substantially longitudinally through the rotor 46, with openings 72 and 74 (e.g., rotor ports) at each end symmetrically disposed about the longitudinal axis 68. The openings 72 and 74 of the rotor 46 are disposed to be in hydraulic communication with the inlet and outlet apertures 76 and 78 (e.g., end cover inlet and end cover outlet ports) and 80 and 82 (e.g., end cover inlet and end cover outlet ports) of the end covers 64 and 66 in such a way that the channels 70 are exposed to high and low pressure fluids during rotation. As shown, the inlet and outlet apertures 76 and 78, as well as 80, 82, may be designed in the form of an arc or a portion of a circle (e.g., C-shaped).

[0032] In some embodiments, a controller (e.g., of FIGS. 1A-B) using sensor data (e.g., revolutions per minute measured via a tachometer or optical encoder, or volumetric flow rate measured via a flow meter) may control the degree of mixing between the first and second fluids in the rotary PX 40, which can be used to improve the operability of a fluid treatment system (e.g., fluid treatment systems 100A-100B of FIGS. 1A-1B). In some examples, by varying the volumetric flow rates of the first and / or second fluids entering the rotary PX 40, an operator (e.g., system operator, plant operator) can control the amount of fluid mixing in the PX 40. Additionally, varying the rotational speed of the rotor 46 (e.g., via a motor) can also allow the operator to control mixing. Three characteristics of the rotary PX 40 that affect mixing include (1) the aspect ratio of the rotor channel 70, (2) the exposure time between the first and second fluids, and (3) the creation of a fluid barrier (e.g., interface) between the first and second fluids in the rotor channel 70. First, the rotor channel 70 (e.g., a duct) is generally long and narrow, stabilizing the flow in the rotary PX 40. Furthermore, the first and second fluids may move through the channel 70 in a plug-flow manner with minimal axial mixing. Second, in certain embodiments, the speed of the rotor 46 reduces contact between the first and second fluids. For example, the speed of the rotor 46 (e.g., a rotor speed of about 1200 RPM (revolutions per minute)) may reduce the contact time between the first and second fluids to less than about 0.15 seconds, 0.10 seconds, or 0.05 seconds. Third, a small portion of the rotor channel 70 is used to exchange pressure between the first and second fluids. This leaves a certain amount of fluid in the channel 70 as a barrier between the first and second fluids. Any such mechanism may limit mixing within the rotary PX 40. Additionally, in some embodiments, the rotary PX 40 may be designed to operate with a full or partial internal piston or other barrier (e.g., a physical barrier) that isolates the first and second fluids while still allowing pressure transfer.

[0033] 2B-2E are exploded views of one embodiment of the rotary PX 40, illustrating the sequence of positions of a single rotor channel 70 within the rotor 46 as the channel 70 rotates through one complete cycle. Note that FIGS. 2B-2E are simplified views of the rotary PX 40, illustrating one rotor channel 70, and that the channel 70 is illustrated as having a circular cross-sectional shape. In other embodiments, the rotary PX 40 may include multiple channels 70 having the same or different cross-sectional shapes (e.g., circular, elliptical, square, rectangular, polygonal, etc.). Thus, FIGS. 2B-2E are simplified for illustrative purposes, and other embodiments of the rotary PX 40 may have different configurations than those shown in FIGS. 2A-2E. As described in more detail below, the rotary PX 40 facilitates pressure exchange between a first fluid and a second fluid (e.g., a hot geothermal fluid and a process fluid) by allowing the first and second fluids to briefly contact each other within the rotor 46. In some embodiments, the PX facilitates pressure exchange between the first and second fluids by allowing the first and second fluids to contact on opposing faces of a barrier (e.g., a reciprocating barrier, piston, not shown). In certain embodiments, this exchange occurs at a rate that limits intermixing of the first and second fluids. The speed of the pressure wave passing through the rotor channel 70 (once the channel is exposed to the aperture 76), the rate of diffusion of the fluids, and / or the rotational speed of the rotor 46 can determine whether and to what extent any intermixing occurs.

[0034] FIG. 2B is an exploded perspective view of one embodiment of a rotary PX 40 (e.g., a rotary LPC) according to certain embodiments. In FIG. 2B, the channel opening 72 is in a first position. In the first position, the channel opening 72 is in fluid communication with an aperture 78 in the end cover 64 and thus with the manifold 52, while the opposite channel opening 74 is in hydraulic communication with an aperture 82 in the end cover 66 and extends therefrom to be in hydraulic communication with the manifold 54. The rotor 46 may rotate in a clockwise direction as indicated by arrow 84. In operation, a low pressure second fluid 86 (e.g., a low pressure slurry fluid) passes through the end cover 66 and into the channel 70 where it contacts the first fluid 88 at a dynamic fluid interface 90. The second fluid 86 then drives the first fluid 88 through the end cover 64, out of the channel 70, and out of the rotary PX 40. However, due to the short contact time, there is minimal mixing between the second fluid 86 (e.g., a slurry fluid) and the first fluid 88 (e.g., a particle-free fluid). In some embodiments, the low pressure second fluid 86 contacts a first face of a barrier (e.g., a piston, not shown) disposed within the channel 70, which is contacted by the first fluid 88 (on the opposite face of the barrier). The second fluid 86 drives the barrier, pushing the first fluid 88 out of the channel 70. In such embodiments, there is negligible mixing between the second fluid 86 and the first fluid 88.

[0035] 2C is an exploded perspective view of one embodiment of a rotating PX 40 (e.g., a rotating LPC) according to certain embodiments. In FIG. 2C, the channel 70 has been rotated clockwise through an arc of approximately 90 degrees. In this position, the opening 74 (e.g., outlet) is no longer in fluid communication with the apertures 80 and 82 of the end cover 66, and the opening 72 is no longer in fluid communication with the apertures 76 and 78 of the end cover 64. Thus, a low pressure second fluid 86 is temporarily contained within the channel 70.

[0036] FIG 2D is an exploded perspective view of one embodiment of a rotating PX 40 (e.g., a rotating LPC) in accordance with certain embodiments. In FIG 2D, the channel 70 has been rotated through an arc of approximately 60 degrees from the position shown in FIG 2B. The opening 74 is now in fluid communication with the aperture 80 in the end cover 66, and the opening 72 of the channel 70 is now in fluid communication with the aperture 76 in the end cover 64. In this position, a first fluid 88 at high pressure enters and pressurizes a second fluid 86 at low pressure, forcing the second fluid 86 out of the rotor channel 70 through the aperture 80.

[0037] FIG 2E is an exploded perspective view of one embodiment of a rotary PX 40 (e.g., a rotary LPC) in accordance with certain embodiments. In FIG 2E, the channel 70 has rotated through an arc of approximately 270 degrees from the position shown in FIG 2B. In this position, the opening 74 is no longer in fluid communication with the apertures 80 and 82 in the end cover 66, and the opening 72 is no longer in fluid communication with the apertures 76 and 78 in the end cover 64. Thus, the first fluid 88 is no longer pressurized and is temporarily retained within the channel 70 until the rotor 46 rotates another 90 degrees to begin the cycle again.

[0038] 3A-C are schematic diagrams of a geothermal power generation system including a PX, according to certain embodiments. Some of the features in one or more of Figures 3A-C may have similar features, functions, and / or structure in one or more of Figures 1A-B and / or one or more of Figures 2A-E.

[0039] 3A is a schematic diagram of a geothermal power generation system 300A including a pressure exchanger (PX) according to certain embodiments. In some embodiments, the geothermal power generation system includes a pressure exchanger (PX) 310. The PX 310 can be a rotary pressure exchanger. In some embodiments, the PX 310 is an isobaric or substantially isobaric pressure exchanger. The PX 310 can be configured to exchange pressure between a first fluid and a second fluid.

[0040] In some embodiments, the geothermal power generation system 300A includes a high pressure (HP) source (e.g., one or more of the HPin systems 132 of FIGS. 1A-D). The HP source can be a source of a first fluid. The first fluid can be a geothermal fluid (e.g., water, brine). In some embodiments, the HP source is a hydrothermal reservoir 334. The hydrothermal reservoir 334 is underground and can be beneath a subsurface rock formation. The hydrothermal reservoir 334 can be a soil heat source of warm fluid. In some embodiments, a production well 302 is in fluid communication with the hydrothermal reservoir 334 and has been drilled through the subsurface rock formation to provide high temperature, high pressure geothermal fluid (e.g., brine and / or water). In some embodiments, the geothermal fluid is provided at a pressure between about 150 bar and about 250 bar (about 15 MPa and about 25 MPa) and a temperature between about 180 degrees Celsius and about 200 degrees Celsius. High temperature and high pressure geothermal fluid may flow from a production well 302 to a high pressure inlet of the PX 310. In some embodiments, the PX 310 separates a first fluid (e.g., geothermal fluid) and a second fluid (e.g., a process fluid, CO 2 , hydrofluorocarbons such as R134a, R245fa, etc., hydrocarbons such as isobutane, pentane, propane, etc., power cycle fluids). In some embodiments, the second fluid is used to drive a turbine.

[0041] In some embodiments, PX310 receives a first fluid at a high pressure (e.g., HPin fluid 130 of FIGS. 1A-1B). In some embodiments, PX310 receives a first fluid at a pressure between about 150 bar and 250 bar (about 15 MPa to 25 MPa). PX310 may receive the first fluid via a high pressure inlet (e.g., HPin). In some embodiments, PX310 receives a second fluid at a low pressure (e.g., LPin fluid 120 of FIGS. 1A-B). In some embodiments, PX310 receives a second fluid at a pressure between about 50 bar and 100 bar (about 5 MPa to 10 MPa). PX310 may receive the second fluid via a low pressure inlet (e.g., LPin). Although reference is made to "high pressure" and "low pressure," "high pressure" and "low pressure" may be relative to each other and may not refer to specific pressure values ​​(e.g., the pressure of the HPin fluid 130 is higher than the pressure of the LPin fluid 120). The PX 310 may exchange pressure between the first fluid and the second fluid. In some embodiments, the PX 310 compresses the second fluid with the first fluid at high pressure. The PX 310 may provide the first fluid through a low pressure outlet (e.g., LPout, LPout fluid 140) and the second fluid through a high pressure outlet (e.g., HPout, HPout fluid 150). In some embodiments, the first fluid provided through the low pressure outlet is at low pressure and the second fluid provided through the high pressure outlet is at high pressure. In some embodiments, the first fluid is provided through the low pressure outlet at between about 50 bar and 100 bar (about 5 MPa and 10 MPa). In some embodiments, the second fluid is provided via a high pressure outlet at between about 150 bar and 250 bar (about 15 MPa and 25 MPa). In some embodiments, PX310 compresses the second fluid from a low pressure subcritical state to a high pressure supercritical state (e.g., to a temperature and pressure above the critical point of the second fluid). In some embodiments, PX310 increases the pressure of a second fluid that is already in a supercritical state. In some embodiments, a supercritical fluid (e.g., a fluid in a supercritical state) is a fluid at a temperature and pressure above its critical point, where distinct liquid and gas phases do not exist.In some embodiments, PX310 increases the pressure of the second fluid from a low pressure subcritical liquid state to a high pressure subcritical liquid state. In some embodiments, PX310 acts as a pump (e.g., rather than a compressor). In some embodiments, PX310 increases the pressure of the second fluid from a low pressure subcritical liquid state to a high pressure supercritical state. In some embodiments, the operating mode of PX310 (e.g., whether the second fluid is in a subcritical liquid state or a supercritical state) is determined by thermodynamic cycle optimization to maximize cycle efficiency while reducing equipment costs.

[0042] In some embodiments, the geothermal power generation system 300A includes a primary heat exchanger (HX) 326. In some embodiments, the primary HX 326 converts geothermal heat from a high pressure first fluid (e.g., water, brine, geothermal fluid) to a low temperature second fluid (e.g., process fluid, CO 2 ) to increase the temperature of the second fluid before it enters the turbine 328. The primary heat exchanger 326 transfers the high temperature geothermal fluid and a high pressure process fluid (e.g., high pressure gaseous CO 2 , high pressure liquid CO 2 , or high pressure supercritical CO 2 ). In some embodiments, the primary heat exchanger 326 receives the first fluid at a temperature between about 180 degrees Celsius and about 200 degrees Celsius. In some embodiments, the primary heat exchanger 326 receives the second fluid at a temperature between about 50 degrees Celsius and about 100 degrees Celsius. In some embodiments, the primary heat exchanger 326 is configured to exchange corresponding thermal energy between the first fluid and the second fluid. In some embodiments, the second fluid is heated by the first fluid in the primary heat exchanger 326. In some embodiments, the first fluid is cooled by the primary heat exchanger 326. From the primary heat exchanger 326, the cooled first fluid may flow to the reinjection well 304, where the cooled first fluid may be reinjected into the hydrothermal formation 334. In some embodiments, the second fluid is heated in the primary heat exchanger 326 to a temperature between about 170 degrees Celsius and about 190 degrees Celsius.

[0043] In some embodiments, the heated second fluid from the primary heat exchanger 326 is provided to a turbine 328. The turbine 328 converts the supercritical CO 2 The turbine 328 may be configured to pass a supercritical fluid, such as a second fluid, through the turbine 328. The second fluid may expand across the blades of the turbine 328, causing the turbine blades and shaft to rotate. In some embodiments, a generator 330 coupled to the turbine shaft may be rotated and electricity may be produced. An input shaft of the generator 330 may be mechanically coupled to an output shaft of the turbine 328 such that the input shaft of the generator 330 rotates with the output shaft of the turbine 328. In some embodiments, the generator 330 may be configured to pass a supercritical fluid, such as a second fluid, through the turbine 328. The second fluid may expand across the blades of the turbine 328, causing the turbine blades and shaft to rotate ... 2 , supercritical CO 2 ) into kinetic energy (e.g., rotational kinetic energy). In some embodiments, the second fluid is output from turbine 328 at a reduced temperature and reduced pressure. In some embodiments, the second fluid is output from turbine 328 at a temperature between about 80 degrees Celsius and about 110 degrees Celsius and a pressure between about 60 bar and 90 bar (about 6 MPa and 9 MPa). In some embodiments, the second fluid is output from turbine 328 in a low pressure subcritical gas phase. In some embodiments, the second fluid is output from turbine 328 in a supercritical state.

[0044] In some embodiments, the second fluid output from the turbine 328 is fed to a recuperator 332 (e.g., a heat exchanger, a secondary heat exchanger). In some embodiments, the recuperator 332 extracts thermal energy remaining after expansion through the turbine 328 and transfers the residual thermal energy to the fluid stream being heated in the primary HX 326. This may reduce the amount of heat that needs to be added in the primary HX 326 for a given amount of power output from the turbine 328 and increase the efficiency of the power generation cycle. In some embodiments, the recuperator 332 is a heat exchanger that exchanges thermal energy between two fluid streams (e.g., a hot stream and a cold stream). The low pressure second fluid exiting the turbine 328 may have some residual thermal energy and may have a warmer temperature than the high pressure second fluid exiting the PX 310. To extract the residual thermal energy, the second fluid output from the turbine 328 is channeled through a recuperator 332 to exchange the corresponding thermal energy with the high pressure second fluid received from the PX 310. The second fluid input to the primary heat exchanger 326 may be heated in the recuperator 332 (e.g., by the second fluid output from the turbine 328). The second fluid received from the PX 310 may be heated in the recuperator 332 before being input to the primary heat exchanger 326. In some embodiments, the second fluid received from the turbine 328 is output from the recuperator 332 at a temperature between about 30 degrees Celsius and about 50 degrees Celsius.

[0045] In some embodiments, the gas cooler 318 receives the second fluid output from the recuperator 332 and further cools the second fluid. Any heat not recovered from the second fluid in the recuperator 332 may be rejected to a corresponding environment (e.g., the surrounding environment) via the gas cooler 318. In some embodiments, the gas cooler 318 acts as a heat sink for the power generation cycle. The gas cooler may increase the density of the second fluid entering the LPin port of the PX 310 and into the suction of the compressor 322. By increasing the density of the second fluid entering the PX 310 (e.g., via the LPin port), the efficiency of the power generation cycle may be increased. In some embodiments, by decreasing the temperature at which the rejection of heat (e.g., via the gas cooler 318) occurs, the Carnot efficiency of the power generation cycle may be increased. In some embodiments, the gas cooler 318 cools the second fluid using air or a cooling liquid (e.g., cooling water). One or more fans may flow air through the cooling channels of the gas cooler 318 to cool the second fluid. In some embodiments, the second fluid cooled in the gas cooler 318 remains in a supercritical liquid state. In some embodiments, the second fluid cooled in the gas cooler 318 may be in a subcritical liquid state (see, e.g., FIG. 3D and associated discussion below). In some embodiments, the cooled second fluid is output from the gas cooler 318 at a pressure between about 50 bar and about 100 bar (about 5 MPa and about 10 MPa) and a temperature between about 15 degrees Celsius and about 35 degrees Celsius.

[0046] In some embodiments, the second fluid flowing from the gas cooler 318 is split into two streams by the flow splitter valve 320. In some embodiments, the flow splitter valve 320 is a three-way valve that splits the second fluid flow along two flow paths. The flow splitter valve 320 may be actuated by a valve actuator. The actuator may actuate the flow splitter valve 320 based on a command received from the controller 380. The command may be based on sensor data from one or more sensors of the geothermal power generation system 300A that is received by the controller 380. In some embodiments, the flow splitter valve 320 directs at least a portion of the second fluid output from the gas cooler 318 toward a low pressure inlet of the PX 310 to exchange pressure with the high pressure first fluid within the PX 310. In some embodiments, the flow splitter valve 320 directs all of the second fluid output from the gas cooler 318 to a low pressure inlet of the PX 310 to exchange pressure with the high pressure first fluid within the PX 310 (e.g., by bypassing the compressor 322, in response to the PX 310 performing sufficient pressure exchange). In some embodiments, the flow splitter valve 320 directs at least a portion of the second fluid output from the gas cooler 318 to the compressor 322. In some embodiments, the flow splitter valve 320 directs all of the second fluid output from the gas cooler 318 to the compressor 322 (e.g., by bypassing the PX 310 during servicing of the PX 310). In some embodiments, the compressor 322 raises the pressure of that portion of the second fluid to a pressure similar (e.g., substantially similar) to the pressure of the high pressure second fluid output from the PX 310. In some embodiments, the compressed second fluid output from compressor 322 is mixed with the high pressure second fluid output from PX 310 in flow combining valve 324. Flow combining valve 324 may be an actuatable three-way valve that is actuated based on commands received from controller 380. In some embodiments, flow combining valve 324 operates according to the actuation of flow splitter valve 320. In some embodiments, system 300A includes a simple pipe branch (e.g., a "T" junction) in place of flow combining valve 324 to combine the two streams.

[0047] In some embodiments, only a portion of the second fluid flows through the compressor 322. For example, about 70% of the second fluid output from the gas cooler 318 may flow through the PX 310 and about 30% of the second fluid may flow through the compressor 322. In other examples, about 80% of the second fluid may flow through the PX 310 and about 20% of the second fluid may flow through the compressor 322. In other examples, about 90% of the second fluid may flow through the PX 310 and about 10% of the second fluid may flow through the compressor 322. In other examples, more than about 95% of the second fluid may flow through the PX 310 and less than about 5% of the second fluid may flow through the compressor 322. In some embodiments, the flow through the compressor 322 is determined based on flow data and / or pressure data. In some embodiments, the combined flow output from the compressor and the high pressure outlet of PX 310 meets a threshold condition (e.g., a flow rate threshold). Depending on the mass flow rate from the high pressure outlet of PX 310, more or less fluid may be passed through the compressor 322. For example, if the mass flow rate from the high pressure outlet of PX 310 is low (e.g., relatively low), the flow splitter valve 320 may be actuated to allow more fluid to pass through the compressor 322. In another example, if the mass flow rate from the high pressure outlet of PX 310 is high (e.g., relatively high, sufficiently high), the flow splitter valve 320 may be actuated to allow less fluid to pass through the compressor 322.

[0048] In some embodiments, the PX uses the pressure energy of a fluid (e.g., water or brine) coming from a geothermal well to generate electricity by converting the working fluid (e.g., CO) of the power generation cycle into heat energy without consuming any external mechanical or electrical energy. 2 ), thus reducing the energy consumed by the compressor 322 in the power cycle. This may increase the efficiency of the power cycle.

[0049] 3B is a schematic diagram of a geothermal power generation system 300B including a pressure exchanger (PX), according to certain embodiments. In some embodiments, features having similar reference numbers to those in other figures have similar properties, structure, and / or functionality as those described in the other figures. In some examples, features of geothermal power generation system 300B have similar properties, structure, and / or functionality as geothermal power generation system 300A of FIG. 3A.

[0050] In some embodiments, the geothermal power generation system 300B includes a motor 360 coupled to a rotor of the PX 310. The motor 360 may control the rotation of the rotor of the PX 310. In some embodiments, the motor 360 regulates the mass flow that may be compressed (or pumped) by the PX 310 and regulates the mass flow rate of the first fluid (e.g., water, brine, geothermal fluid) and the second fluid (e.g., process fluid, CO 2 ) to reduce the amount of mixing that may occur between the first and second fluids. In some embodiments, motor 360 controls the rotational speed (e.g., angular velocity, rotational speed) of PX 310. In some embodiments, the pressure of the second fluid output from PX 310 may be related to the rotational speed of PX 310. In some embodiments, a controller (e.g., controller 380) receives sensor data from one or more sensors of motor 360. In some embodiments, motor 360 is an electric motor. In some embodiments, controller 380 controls motor 360. Motor 360 may be controlled based on sensor data associated with the high pressure flow output from the high pressure outlet of PX 310, such as pressure data and / or flow rate data. In some embodiments, controller 380 receives motor data from one or more motor sensors (e.g., speed sensor, runtime sensor, load sensor) associated with motor 360. The motor data received from the motor sensors may include the current motor speed (e.g., revolutions per minute), the total runtime of the motor, the runtime of the motor between maintenance activities, and / or the total number of revolutions of the motor, etc. The motor data may represent a performance status of the motor 360 .

[0051] 3C is a schematic diagram of a geothermal power generation system 300C including a pressure exchanger (PX) according to certain embodiments. In some embodiments, features having similar reference numbers to those in other figures have similar properties, structure, and / or functionality as those described in the other figures. In some examples, features of geothermal power generation system 300C have similar properties, structure, and / or functionality as geothermal power generation system 300A of FIG. 3A or geothermal power generation system 300B of FIG. 3B.

[0052] In some embodiments, hot geothermal fluid is received via production well 302 from fractured hot rock 335 underlying a subsurface rock formation. The fractured hot rock 335 may have been fractured by "fracking." In some embodiments, the cooled, low pressure geothermal fluid output from primary heat exchanger 326 is reinjected into the fractured hot rock 335 via reinjection well 304. In some embodiments, injection pump 336 increases the pressure of the geothermal fluid output from primary heat exchanger 326 and reinjects the geothermal fluid into the fractured hot rock 335.

[0053] FIGURE 3D is a schematic diagram of a geothermal power generation system 300D including a pressure exchanger (PX) according to certain embodiments. In some embodiments, features having similar reference numbers to those in other figures have similar properties, structure, and / or functionality as described in the other figures. In some examples, features of the geothermal power generation system 300C have similar properties, structure, and / or functionality as the geothermal power generation system 300A of FIGURE 3A, the geothermal power generation system 300B of FIGURE 3B, or the geothermal power generation system 300C of FIGURE 3C.

[0054] In some embodiments (e.g., embodiments in which the fluid in the gas cooler 318 is in a subcritical liquid state), the system 300D may include a pump 323. In some embodiments, the PX 310 acts as a compressor and / or a pump. For example, the PX 310 may process both the supercritical state of the fluid at the first inlet (e.g., LPin) and the subcritical liquid state of the fluid at the first inlet. In some embodiments, the use of a pump 323 rather than a compressor (e.g., compressor 322 in FIGS. 3A-3C) may allow the power generation cycle to operate in a “transcritical” mode. In the “transcritical” mode, the second fluid (CO 2 ) is pumped from a low pressure subcritical liquid state to a high pressure liquid state using PX 310 and pump 323. Heat added in the primary HX 326 is converted into CO 2 The working fluid may be converted from a high pressure liquid state to a high pressure supercritical state. In some embodiments, both the pressure and temperature of the working fluid leaving the primary HX 326 are above the critical point. In some embodiments, the energy consumed by the pump is less than the energy consumed by the compressor, which allows the working fluid (e.g., CO 2 The energy required to increase the pressure of the refrigerant (CO) from low pressure to high pressure can be reduced.

[0055] 4 is a schematic diagram of a geothermal power generation system 400, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to those in other figures have similar properties, structure, and / or functionality as described in the other figures. In some examples, features of geothermal power generation system 400 have similar properties, structure, and / or functionality as geothermal power generation systems 300A-300C of FIGS. 3A-C.

[0056] In some embodiments, the geothermal power generation system 400 includes a circulation pump 430. In some embodiments, the circulation pump 430 increases the pressure of the geothermal fluid received from the hydrothermal formation 334 to overcome pressure losses within the system (e.g., the geothermal power generation system 400). In some embodiments, the circulation pump 430 pumps the geothermal fluid to maintain a consistent (e.g., substantially consistent) flow rate of the geothermal fluid from the hydrothermal formation 334. In some embodiments, the circulation pump 430 is controlled by the controller 380. For example, the controller 380 can send commands to a motor (e.g., a motor controller) associated with the circulation pump 430 to increase or decrease the output of the circulation pump 430 to meet the flow rate or pressure demands of the system.

[0057] In some embodiments, the geothermal power generation system 400 includes a second fluid (e.g., a process fluid, supercritical CO 2 ) to supply the second fluid to PX 310. In some embodiments, the low pressure booster 414 is a compressor. In some embodiments, the low pressure booster 414 is a pump (see, e.g., FIG. 5B). In some embodiments, the low pressure booster 414 channels the low pressure second fluid to maintain a consistent (e.g., substantially consistent) flow rate of the second fluid to PX 310. In some embodiments, the low pressure booster 414 channels the low pressure second fluid to supply an optimal mass flow rate of the second fluid to PX 310. For example, the low pressure booster 414 may be configured to ensure that the rotor channels of PX 310 are able to pump CO during operation. 2 The PX310 should be optimally filled (e.g., nearly completely filled) with supercritical CO to maintain optimal operation. 2In some embodiments, the low pressure booster 414 is controlled by the controller 380. For example, the controller 380 can send commands to a motor (e.g., a motor controller) associated with the low pressure booster 414 to increase or decrease the flow output of the low pressure booster 414 to meet the flow or pressure demands of the system.

[0058] 5A is a schematic diagram of a geothermal power generation system 500A, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to those in other figures have similar properties, structure, and / or functionality as described in the other figures. In some examples, features of the geothermal power generation system 500A have similar properties, structure, and / or functionality as the geothermal power generation systems 300A-400 of FIGS. 3A-4.

[0059] In some embodiments, the geothermal power generation system 500A includes a high pressure booster 524. In some embodiments, the high pressure booster 524 is a compressor. In some embodiments, the high pressure booster 524 is a pump (see, for example, FIG. 5B). The high pressure booster 524 may receive a high pressure second fluid from the PX 310 and provide the second fluid to the flow junction valve 324. In some embodiments, the output from the high pressure booster is mixed with the output from the compressor 322. In some embodiments, the high pressure booster 524 increases the pressure of the second fluid received from the HPout port of the PX 310 by a small amount. In some examples, the high pressure booster 524 may increase the pressure of the second fluid by less than about 50 PSI. The high pressure booster 524 may increase the pressure of the second fluid to overcome flow resistance and / or pressure losses in the system. The high pressure booster 524 may be configured to supply the second fluid with a consistent (e.g., substantially consistent) high pressure CO 2 to the turbine 328. 2In some embodiments, high pressure booster 524 is controlled by controller 380. For example, controller 380 can send commands to a motor (e.g., a motor controller) associated with high pressure booster 524 to increase or decrease the pressure output of high pressure booster 524 to meet the flow or pressure demands of the system.

[0060] 5B is a schematic diagram of a geothermal power generation system 500B, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to reference numbers in other figures have similar properties, structure, and / or functionality as described in the other figures. In some examples, features of geothermal power generation system 500B have similar properties, structure, and / or functionality as geothermal power generation systems 300A-500A of FIGS. 3A-5A.

[0061] In some embodiments, the HP booster 524 is a pump that receives the second fluid in a liquid state at high pressure from the PX 310 and supplies the second fluid (e.g., at a liquid state and with an increased pressure) to the flow junction valve 324. In some embodiments, the LP booster 414 is a pump that receives the second fluid in a liquid state at low pressure and supplies the second fluid (e.g., at a liquid state and with an increased pressure) to a low pressure inlet of the PX 310.

[0062] 6 is a schematic diagram of a geothermal power generation system 600, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to reference numbers in other figures have similar properties, structures, and / or functions as those described in the other figures. In some examples, features of geothermal power generation system 600 have similar properties, structures, and / or functions as geothermal power generation systems 300A-500 of FIGS. 3A-5B.

[0063] In some embodiments, the geothermal power generation system 600 includes a low pressure gas-liquid separator 614 (e.g., a low pressure flash tank, a low pressure receiver) and a high pressure gas-liquid separator 616 (e.g., a high pressure flash tank, a low pressure receiver). The low pressure gas-liquid separator 614 may be a receiver having a chamber that receives a fluid and separates the fluid into a gas and a liquid. In some embodiments, the gas-liquid separators 614 and 616 may be "cyclonic" separators that separate the fluid through centrifugal motion of the fluid. In some embodiments, in a cyclonic separator, the denser fluid is driven more radially outward in the separator during centrifugal motion of the mixed fluid and is captured in a separated section in the separator. In some embodiments, the low pressure gas-liquid separator 614 may receive at least the low pressure first fluid (e.g., low pressure geothermal fluid) output from the low pressure outlet of the PX 310. In some embodiments, the low pressure gas-liquid separator 614 separates at least a portion of the second fluid (e.g., at least CO) that is mixed with the first fluid in the PX 310. 2 ) may be received. In some embodiments, mixing of the first and second fluids may be reduced and / or eliminated by spinning the rotor of the PX310 faster. The fluid received in the chamber of the low pressure gas-liquid separator 614 may be separated into liquid and gas. The liquid (e.g., geothermal fluid) will sink to the bottom of the chamber and the gas (e.g., CO2) will rise. 2 ) may rise to the top.

[0064] In some embodiments, a second fluid (e.g., a process fluid, CO) mixed with the first fluid is 2) may be in a supercritical state but still be separated in the gas-liquid separator 614 due to density differences compared to the first fluid. In some embodiments, for example in the case of a transcritical cycle, the second fluid may be in a liquid state similar to that of the first fluid. In some embodiments, the gas-liquid separators 614 and 616 may act as liquid-liquid separators since the density of the second fluid (which is in a liquid state) may be different than the density of the first fluid (which is in a liquid state) and thus separated from the top of the separator. By separating the gas and liquid in the low pressure gas-liquid separator 614, loss of the second fluid from the system may be prevented since a small amount of the second fluid separated in the separator 614 is returned to the second fluid loop. In some embodiments, the gas is separated from the top of the low pressure gas-liquid separator 614 by the high pressure second fluid (e.g., high pressure CO 2 ) output from the PX 310 towards the primary heat exchanger 326. 2 ) flow from the bottom of the low pressure liquid / gas separator 614 to the primary heat exchanger 326. In some embodiments, liquid (e.g., high temperature geothermal fluid) may flow from the bottom of the low pressure liquid / gas separator 614 to the primary heat exchanger 326.

[0065] The high pressure liquid / gas separator 616 may be referred to as a receiver having a chamber that receives a fluid and separates the fluid into gas and liquid. In some embodiments, the high pressure liquid / gas separator 616 receives the high pressure second fluid (e.g., high pressure CO2) output from the high pressure outlet of the PX 310. 2 ) in the high pressure liquid / gas separator 616. In some embodiments, the high pressure liquid / gas separator 616 may receive at least a portion of the first fluid (e.g., at least a portion of the geothermal fluid) that has been mixed with the second fluid in the PX 310. The fluid received in the chamber of the high pressure liquid / gas separator 616 may be separated into liquid and gas. The liquid (e.g., geothermal fluid) will sink to the bottom of the chamber and the gas (e.g., CO 2) may rise to the top. Separating the gas and liquid in the high pressure gas-liquid separator 616 may prevent liquid (e.g., the liquid first fluid) from reaching the inlet and entering the turbine 328. In some embodiments, gas may flow from the top of the high pressure gas-liquid separator 616 to the flow merging valve 324 and then to the primary heat exchanger 326. In some embodiments, liquid (e.g., high temperature geothermal fluid) may flow from the bottom of the high pressure gas-liquid separator 616 to the low pressure first fluid stream output from the PX 310 to the primary heat exchanger 326.

[0066] 7 is a schematic diagram of a geothermal power generation system 700, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to reference numbers in other figures have similar properties, structures, and / or functions as described in the other figures. In some examples, features of geothermal power generation system 700 have similar properties, structures, and / or functions as geothermal power generation systems 300A-600 of FIGS. 3A-6.

[0067] In some embodiments, the geothermal power generation system 700 includes a residue compressor 724 that increases the pressure of the gas collected in the low pressure gas-liquid separator 614. Because the gas collected in the low pressure gas-liquid separator 614 is at low pressure (e.g., between about 50 bar and about 100 bar (about 5 MPa and about 10 MPa)) and the high pressure second fluid output from the PX 310 is at high pressure (e.g., between about 150 bar and about 250 bar (about 15 MPa and about 25 MPa)), the residue compressor 724 increases the pressure of the gas to overcome the pressure difference so that it can be mixed with the output from the compressor 322 and the PX 310 (e.g., injected into the high pressure stream of the second fluid). In some embodiments, the residue compressor 724 can flow a trace amount of gas collected in the low pressure gas-liquid separator 614. In some embodiments, the retentate compressor 724 is controlled by the controller 380. For example, the controller 380 can send commands to a motor (e.g., a motor controller) associated with the retentate compressor 724 to increase or decrease the pressure output of the retentate compressor 724 to meet the flow or pressure demands of the system.

[0068] In some embodiments, the geothermal power generation system 700 includes a high pressure valve 748 that reduces the pressure of the liquid collected in the high pressure liquid separator 616. The high pressure valve 748 may reduce the pressure of the liquid output from the high pressure liquid separator 616 to substantially match the pressure of the liquid output from the low pressure liquid separator 614 (e.g., between about 50 bar and 100 bar (about 5 MPa and 10 MPa)). In some embodiments, the high pressure valve 748 is controlled by the controller 380. For example, the controller 380 may send commands to an actuator associated with the high pressure valve 748 to operate the high pressure valve 748 to open or close to meet the flow or pressure demands of the system.

[0069] In some embodiments, the geothermal power generation system 700 includes a high temperature recuperator 732A (e.g., a CO 2a high-temperature heat exchanger 732B (e.g., a high-temperature heat exchanger configured to exchange heat between two flows of a working fluid, such as a high-temperature heat exchanger configured to exchange heat between two flows of a working fluid, such as a high-temperature heat exchanger 732C (e.g., a high-temperature heat exchanger configured to exchange heat between two flows of a working fluid, such as ... 2 and a low-temperature heat exchanger configured to exchange heat between two flows of a working fluid, such as a low-temperature heat exchanger (e.g., low-pressure CO 2 ), output from the turbine 328. The high-temperature recuperator 732A receives a low-pressure second fluid, such as a low-pressure CO 2 2 ) and a high pressure second fluid (e.g., high pressure CO 2 ) output from the low temperature recuperator 732B. 2 ) and the low temperature recuperator 732B may receive the low pressure second fluid output from the high temperature recuperator 732A and the high pressure second fluid output from the PX 310. In some embodiments, the high temperature recuperator 732A is disposed upstream of the low temperature recuperator 732B along the flow of the second fluid output from the turbine 328. Corresponding thermal energy may be exchanged between the low pressure second fluid and the high pressure second fluid at a first temperature (e.g., high temperature) in the high temperature recuperator 732A and at a second temperature (e.g., low temperature) in the low temperature recuperator 732B. In some embodiments, a portion of the second fluid output from the low temperature recuperator 732B is compressed by the parallel compressor 734 and introduced into the flow of the second fluid from the low temperature recuperator 732B to the high temperature recuperator 732A. In some embodiments, the amount of flow through the parallel compressor 734 may be adjusted to achieve an optimal power generation cycle design to maximize power generation efficiency. A portion of the second fluid compressed by the parallel compressor 734 may receive heat in the hot recuperator 732A. The parallel compressor 734 may be controlled by the controller 380. In some embodiments, the amount of the second fluid compressed by the parallel compressor 734 may be varied to achieve maximum efficiency of the system (e.g., geothermal power generation system 700) by increasing or decreasing the power provided to a drive motor coupled to the parallel compressor 734 (e.g., based on commands from the controller 380).

[0070] 8 is a schematic diagram of a geothermal power generation system 800, including a PX, according to certain embodiments. In some embodiments, features having similar reference numbers to reference numbers in other figures have similar properties, structure, and / or functionality as described in the other figures. In some examples, features of geothermal power generation system 800 have similar properties, structure, and / or functionality as geothermal power generation systems 300A-700 of FIGS. 3A-7.

[0071] In some embodiments, the primary heat exchanger 326 receives geothermal fluid from a production well 302 (e.g., rather than from PX 310 as described above). Corresponding thermal energy is transferred from the first fluid (e.g., from the geothermal fluid) to a second fluid (e.g., CO) in the primary heat exchanger 326 before the first fluid is delivered to PX 310. 2 ) to the primary HX 326. In some embodiments, the high pressure first fluid is cooled in the primary heat exchanger 326 before the high pressure first fluid is delivered to the high pressure inlet of the PX 310. In some examples, the high temperature and high pressure geothermal fluid from the hydrothermal reservoir 334 is too hot to be processed by the PX 310. Therefore, the geothermal fluid may be cooled (by the high pressure second fluid) in the primary heat exchanger 326 before it enters the PX 310. In some embodiments, by exchanging heat of the first fluid (e.g., hot water, brine, fluid from a geothermal well, geothermal fluid) in the primary HX 326 before sending the first fluid to the PX 310, the efficiency of the power generation cycle may be increased and the performance of the PX 310 may be improved.

[0072] FIG. 9 is a flow diagram illustrating a method 900 for controlling a geothermal power generation system (e.g., one or more of geothermal power generation systems 300A-800 of FIGS. 3A-8), according to certain embodiments. In some embodiments, method 900 is performed by processing logic, which may include hardware (e.g., circuits, special purpose circuits, programmable logic, microcode, a processing device, etc.), software (e.g., instructions running on a processing device, a general purpose computer system, or a special purpose machine), firmware, microcode, or a combination thereof. In some embodiments, method 900 is performed, at least in part, by a controller (e.g., control module 180 of FIGS. 1A-B or control module 380 of FIGS. 3A-8). In some embodiments, a non-transitory storage medium stores instructions that, when executed by a processing device (e.g., control module 180 of FIGS. 1A-B or control module 380 of FIGS. 3A-8), cause the processing device to perform method 900.

[0073] For simplicity of explanation, method 900 has been depicted and described as a series of operations, although operations in accordance with the present disclosure may occur in various orders and / or simultaneously, together with other operations not shown and described herein. Moreover, in some embodiments, method 900 in accordance with the subject matter of the present disclosure may be implemented without performing all of the operations shown. In addition, those skilled in the art will understand and appreciate that method 900 may alternatively be represented as a series of interrelated states via a state diagram or events.

[0074] At block 902, processing logic comprises a process for generating a first fluid (e.g., water and / or brine) and a second fluid (e.g., CO) received from a geothermal source (e.g., hydrothermal reservoir 334). 2) via a pressure exchanger (e.g., PX 310). In some examples, processing logic (e.g., of controller 380) can operate the pressure exchanger to exchange pressure between the first fluid and the second fluid. In some embodiments, processing logic can open one or more valves or cause one or more pumps and / or compressors to provide the first fluid and the second fluid to the inlet of the pressure exchanger. One or more valves can be opened or closed and one or more pumps and / or compressors can be controlled based on sensor data, such as temperature sensor data, flow sensor data, and / or pressure sensor data. Processing logic can cause a compressor and / or a booster (e.g., LP booster 414, circulation pump 430) to flow the first fluid and the second fluid through the pressure exchanger based on sensor data (e.g., temperature sensor data, pressure sensor data, flow sensor data). A first fluid may be provided to a first inlet of the pressure exchanger at a first pressure, and a second fluid may be provided to a second inlet of the pressure exchanger at a second pressure. The first pressure may be greater than the second pressure. In some embodiments (e.g., in embodiments where the pressure exchanger is a rotary pressure exchanger), the processing logic may cause a motor (e.g., motor 360) to rotate a rotor of the pressure exchanger. Pressure may be exchanged between the first and second fluids by providing the first and second fluids to the inlets of the pressure exchanger via a compressor and / or a booster and / or rotating the pressure exchanger via the motor. The first fluid may exit the pressure exchanger via a first outlet at a third pressure, and the second fluid may exit the pressure exchanger via a second outlet at a fourth pressure. The third pressure may be less than the fourth pressure.

[0075] At block 904, the processing logic can cause corresponding thermal energy to be provided from the first fluid to a second fluid via a heat exchanger. The second fluid can be, for example, CO. 2 (e.g., supercritical CO 2The first fluid may be a working fluid or a power cycle fluid, such as a geothermal fluid. In some examples, processing logic (e.g., of the controller 380) may operate one or more of the systems 300A-800 to reject heat from the geothermal fluid to a power cycle fluid via the primary heat exchanger 326. The processing logic may actuate one or more valves, operate one or more pumps or compressors, and / or operate a pressure exchanger. In some embodiments, the first fluid may be caused to flow through a heat exchanger (e.g., the primary heat exchanger 326). The first fluid may be at a first temperature upon entering the heat exchanger and at a second (e.g., lower) temperature upon exiting the heat exchanger. The heat exchanger may facilitate heat transfer from the first fluid to the second fluid, increasing the temperature of the second fluid and / or decreasing the temperature of the first fluid.

[0076] At block 906, processing logic may convert the corresponding thermal energy and / or kinetic energy of the second fluid into rotational kinetic energy via a turbine (e.g., turbine 328). In some examples, processing logic (e.g., of controller 380) may convert the corresponding thermal energy and / or kinetic energy of the second fluid into rotational kinetic energy via a turbine (e.g., turbine 328). 2 , supercritical CO 2 ) may flow through a turbine 328. The processing logic may actuate one or more valves, operate one or more pumps or compressors, and / or operate a pressure exchanger. The turbine (e.g., turbine 328) may be configured to receive the power generation cycle fluid output from the heat exchanger (e.g., primary heat exchanger 326). The thermal energy of the second fluid provided to the turbine may be converted to kinetic energy (e.g., rotational kinetic energy). In turn, the turbine may rotate a generator (e.g., generator 330) to produce electricity. In some embodiments, the kinetic energy of the turbine may be used for any work or power generation. The fluid output from the turbine may be routed back to the heat exchanger through one or more additional heat exchangers, compressors, and / or pressure exchangers.

[0077] 10 is a block diagram illustrating a computer system 1000, according to an embodiment. In some embodiments, the computer system 1000 is a client device. In some embodiments, the computer system 1000 is a controller device (e.g., a server, controller 180 of FIGS. 1A-B, controller 380 of FIGS. 3A-8).

[0078] In some embodiments, computer system 1000 is connected to other computer systems (e.g., via a network such as a local area network (LAN), an intranet, an extranet, or the Internet). Computer system 1000 operates in the capacity of a server or client computer in a client-server environment, or as a peer computer in a peer-to-peer or distributed network environment. In some embodiments, computer system 1000 is provided by a personal computer (PC), a tablet PC, a set-top box (STB), a personal digital assistant (PDA), a mobile phone, a web appliance, a server, a network router, switch or bridge, or any device capable of executing a set of instructions (sequential or otherwise) that specify actions to be taken by that device. Furthermore, the word "computer" is intended to include any collection of computers that individually or cooperatively execute a set (or sets) of instructions to implement any one or more of the methods described herein.

[0079] In some embodiments, computer system 1000 includes a processing device 1002, a volatile memory 1004 (e.g., Random Access Memory (RAM)), a non-volatile memory 1006 (e.g., Read-Only Memory (ROM) or Electrically Erasable Programmable ROM (EEPROM)), and / or a data storage device 1016, which communicate with each other via a bus 1008.

[0080] In some embodiments, processing device 1002 includes one or more processors, such as a general purpose processor (e.g., a Complex Instruction Set Computing (CISC) microprocessor, a Reduced Instruction Set Computing (RISC) microprocessor, a Very Long Instruction Word (VLIW) microprocessor, a microprocessor that executes other types of instruction sets, or a combination of multiple types of instruction sets, etc.) or a specialized processor (e.g., an Application Specific Integrated Circuit (ASIC), a Field Programmable Gate Array (FPGA), a Digital Signal Processor (DSP), or a network processor, etc.). In some embodiments, processing device 1002 includes one or more of a single processor, multiple processors, a single processor with multiple processing cores, and / or the like.

[0081] In some embodiments, computer system 1000 further comprises a network interface device 1022 (e.g., coupled to network 1074). In some embodiments, computer system 1000 comprises one or more input / output (I / O) devices. In some embodiments, computer system 1000 also includes a video display unit 1010 (e.g., a liquid crystal display (LCD)), an alphanumeric input device 1012 (e.g., a keyboard), a cursor control device 1014 (e.g., a mouse), and / or a signal generating device 1020.

[0082] In some embodiments, a data storage device 1018 (e.g., disk drive storage, fixed and / or removable storage devices, fixed disk drives, removable memory cards, optical storage, network attached storage (NAS), and / or storage area networks (SAN)) comprises a non-transitory computer-readable storage medium 1024 that stores instructions 1026 that encode any one or more of the methods or functions described herein and are for performing the methods described herein.

[0083] In some embodiments, the instructions 1026 also reside, completely or partially, within the volatile memory 1004 and / or the processing device 1002 during their execution by the computer system 1000. Thus, the volatile memory 1004 and the processing device 1002 also constitute machine-readable media in some embodiments.

[0084] Although computer-readable medium 1024 is shown as a single medium in the illustrative example, the term "computer-readable medium" is intended to include single or multiple media (e.g., centralized or distributed databases and / or associated caches and servers) that store one or more sets of executable instructions. The term "computer-readable medium" is also intended to include any tangible medium that can store or encode a set of instructions for execution by a computer that cause the computer to perform one or more of the methods described herein. The term "computer-readable storage medium" is also intended to include, but is not limited to, solid-state memories, optical media, and magnetic media.

[0085] The methods, components, and features described herein may be performed by individual hardware components or may be integrated into the functionality of other hardware components, such as an ASIC, FPGA, DSP, or similar device. Additionally, the methods, components, and features may be performed by firmware modules or functional circuits within a hardware device. Furthermore, the methods, components, and features may be implemented in any combination of hardware and computer program components, or in a computer program.

[0086] Unless otherwise specified, words such as "operate," "regulate," "cause," "control," "determine," "identify," "provide," "receive," "stream," and similar words refer to actions or processes performed or carried out by a computer system that manipulate and transform data represented as physical quantities (electrical quantities) in the registers or memory of the computer system into other data also represented as physical quantities in the memory or registers of the computer system, or other such information storage, transmission, or display device. Also, as used herein, the words "first," "second," "third," "fourth," and the like, are meant as labels to distinguish different elements and do not necessarily have a hierarchical meaning according to their numerical designations.

[0087] The embodiments described herein also relate to an apparatus for carrying out the methods described herein. The apparatus may be specially configured to carry out the methods described herein, or may comprise a general-purpose computer system selectively programmed by a computer program stored in the computer system. Such a computer program may be stored on a computer-readable tangible recording medium.

[0088] The methods and illustrative examples described herein are not inherently related to any particular computer or other apparatus. Various general-purpose systems may be used in accordance with the teachings described herein, or it may prove convenient to construct more specialized apparatus to perform the methods described herein and / or each of their individual functions, routines, subroutines or operations. Examples of structures for various such systems are set forth in the description above.

[0089] In the foregoing description, numerous specific details are set forth, such as examples of specific systems, components, methods, and the like, to provide a thorough understanding of some embodiments of the present disclosure. However, it will be apparent to one of ordinary skill in the art that at least some embodiments of the present disclosure may be practiced without these specific details. In other instances, well-known components or methods have not been described in detail or have been shown in simple block diagram form to avoid unnecessarily obscuring the present disclosure. Thus, the above specific details are merely exemplary. A particular implementation may differ from these example details and still be considered to be within the scope of the present disclosure.

[0090] Throughout this specification, a reference to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with that embodiment is included in at least one embodiment. That is, the appearance of phrases such as "in one embodiment" or "in an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment. In addition, the word "or" is intended to mean an inclusive "or" rather than an exclusive "or." When the words "about," "substantially," or "approximately" are used herein, this is intended to mean that the nominal value presented is accurate to within 10%. Additionally, the words "first," "second," "third," "fourth," and the like, as used herein, are meant as labels to distinguish different elements and do not necessarily have a hierarchical meaning according to their numerical designations.

[0091] As used herein, the terms "above," "below," "between," "disposed on," and "on" refer to the location of one layer of material or component relative to another layer or component. For example, a layer that is disposed on, above, or below another layer may be in direct contact with the other layer or may have one or more intervening layers. Additionally, a layer that is disposed between two layers may be in direct contact with the two layers or may have one or more intervening layers. Similarly, unless otherwise indicated, a feature that is disposed between two features may be in direct contact with the adjacent feature or may have one or more intervening layers.

[0092] Although the method operations herein are shown and described in a particular order, the order of each method operation may be changed such that certain operations may be performed in reverse order or such that certain operations may be performed at least in part simultaneously with other operations. In other embodiments, the ordering of separate operations or sub-operations may be intermittent and / or alternating. In one embodiment, multiple metallurgical bonding operations are performed as a single step.

[0093] It is to be understood that the above description is intended to be illustrative, and not restrictive. Many other embodiments will be apparent to those of ordinary skill in the art upon reading and understanding the above description. The scope of the present disclosure should therefore be determined with reference to the appended claims, along with the full scope of equivalents to which each claim is entitled.

Claims

1. A system, wherein the system is A pressure exchanger (PX) is configured to receive a first fluid at a first pressure from a geothermal power source via a first inlet of the PX, receive a second fluid at a second pressure via a second inlet of the PX, and exchange pressure between the first fluid and the second fluid, wherein the first fluid exits the PX via a first outlet of the PX at a third pressure, and the second fluid exits the PX via a second outlet of the PX at a fourth pressure. A first flow valve configured to receive the second fluid at the fourth pressure and the third fluid at the fourth pressure, wherein the first flow valve is configured to mix the third fluid with the second fluid, A first heat exchanger configured to exchange corresponding thermal energy between the first fluid at approximately the third pressure and the second fluid at approximately the fourth pressure, A system comprising: a turbine configured to receive the second fluid output from the first heat exchanger and to convert the corresponding energy of the second fluid into rotational kinetic energy.

2. The aforementioned system, The system according to claim 1, further comprising a generator mechanically coupled to the turbine, the generator configured to generate electricity in response to the turbine converting the corresponding thermal energy of the second fluid into kinetic energy.

3. The aforementioned system, The system according to claim 1, further comprising a second heat exchanger, the second heat exchanger receiving a fluid output from the turbine and supplying the corresponding thermal energy from the fluid output from the turbine to the second fluid input to the first heat exchanger, thereby increasing the temperature of the second fluid input to the first heat exchanger.

4. The aforementioned system, The system according to claim 3, further comprising a third heat exchanger configured to receive a fluid output from the second heat exchanger, the third heat exchanger configured to supply the corresponding thermal energy from the fluid output from the second heat exchanger to the corresponding environment.

5. The aforementioned system, A second flow valve is configured to supply the second fluid at the second pressure to the PX and to supply the third fluid at the second pressure, The system further comprises a compressor or pump configured to receive the third fluid at the second pressure from the second flow valve and to raise the pressure of the third fluid to the fourth pressure, The system according to claim 1, wherein the first flow valve is configured to receive the second fluid at the fourth pressure from the PX and the third fluid at the fourth pressure from the compressor, and the first flow valve is further configured to mix the second fluid with the fourth fluid.

6. The system according to claim 1, further comprising a motor coupled to the rotor of the PX, wherein the motor is configured to control the rotational speed of the rotor.

7. The aforementioned system, It's a booster, The second fluid is received and the pressure of the second fluid is raised to the second pressure, and A booster configured to supply the second fluid at the second pressure to the PX through the second inlet, It is a pump, The first fluid is received from the geothermal power source, and the pressure of the first fluid is increased to the first pressure, and The system according to claim 1, further comprising a pump configured to supply the first fluid at the first pressure to the PX through the first inlet.

8. The aforementioned system, It's a booster, The second fluid is received from the second outlet of the PX and the pressure of the second fluid is increased, The system according to claim 1, further comprising a booster configured to supply the second fluid and combine it with the output of the compressor, and to input it to the first heat exchanger.

9. The aforementioned system, A first receiver configured to receive the first fluid from the first outlet of the PX, the first receiver forming a first chamber configured to separate the first fluid into a first gas and a first liquid, The system according to claim 1, further comprising: a second receiver configured to receive the second fluid from the second outlet of the PX, the second receiver forming a second chamber configured to separate the second fluid into a second gas and a second liquid.

10. The aforementioned system, The first compressor, The first receiver receives the first gas, increases the pressure of the first gas, and The system according to claim 9, further comprising a first compressor configured to supply the first gas and combine it with the output of the second compressor, and to input it to the first heat exchanger.

11. The aforementioned system, A second heat exchanger, configured to receive the second fluid output from the turbine and to supply the corresponding thermal energy from the second fluid to a fourth fluid, thereby increasing the temperature of the fourth fluid, A third heat exchanger, configured to receive the second fluid output from the second heat exchanger and to supply the corresponding thermal energy from the second fluid to the fourth fluid, thereby raising the temperature of the fourth fluid, The system according to claim 1, further comprising: a compressor configured to receive at least a portion of the second fluid output from the third heat exchanger, increase the pressure of the at least portion of the second fluid, and supply the at least portion of the second fluid to combine with the fourth fluid to form the fourth fluid.

12. The first heat exchanger is, To receive the first fluid of the third pressure output from the PX, or The system according to claim 1, configured to receive the first fluid from the geothermal power source and to supply the first fluid to the PX at a first pressure.

13. The second fluid is carbon dioxide (CO2). ２ The system according to claim 1, comprising one or more of the following: ), hydrofluorocarbons, or hydrocarbons.

14. The system according to claim 1, wherein the first pressure is higher than the second pressure, and the third pressure is lower than the fourth pressure.

15. A method, wherein the said method is The pressure exchange is to occur between a first fluid and a second fluid received from a geothermal power source via a pressure exchanger (PX), wherein the PX reduces the pressure of the first fluid from a first pressure to a third pressure and increases the pressure of the second fluid from a second pressure to a fourth pressure. The third fluid is mixed with the second fluid via a first flow valve configured to receive the second fluid at the fourth pressure and the third fluid at the fourth pressure, To ensure that the corresponding thermal energy is supplied via the first heat exchanger from the first fluid at approximately the third pressure to the second fluid at approximately the fourth pressure, A method comprising causing the conversion of the corresponding energy of the second fluid into rotational kinetic energy via a turbine.

16. The method according to claim 15, wherein the PX receives the first fluid at a first pressure from the geothermal supply source through a first inlet of the PX, and the PX receives the second fluid at a second pressure through a second inlet of the PX, the PX exchanges pressure between the first fluid and the second fluid, the first fluid exits the PX through a first outlet of the PX at a third pressure, and the second fluid exits the PX through a second outlet of the PX at a fourth pressure.

17. The aforementioned method, To cause the separation of the first fluid output from the PX into a first gas and a first liquid via a first receiver forming a first chamber, The method according to claim 15, further comprising causing the second fluid output from the PX to separate into a second gas and a second liquid via a second receiver forming a second chamber.

18. A non-temporary computer-readable recording medium comprising a command that causes a processing device to perform an operation when executed by the processing device, wherein the operation is: The pressure exchange is to occur between a first fluid and a second fluid received from a geothermal power source via a pressure exchanger (PX), wherein the PX reduces the pressure of the first fluid from a first pressure to a third pressure and increases the pressure of the second fluid from a second pressure to a fourth pressure. The third fluid is mixed with the second fluid via a first flow valve configured to receive the second fluid at the fourth pressure and the third fluid at the fourth pressure, To ensure that the corresponding thermal energy is supplied via the first heat exchanger from the first fluid at approximately the third pressure to the second fluid at approximately the fourth pressure, A non-temporary computer-readable recording medium comprising: causing the conversion of the corresponding energy of the second fluid into rotational kinetic energy via a turbine.

19. The non-temporary computer-readable recording medium according to claim 18, wherein the PX receives the first fluid at a first pressure from the geothermal supply source through a first inlet of the PX, and the PX receives the second fluid at a second pressure through a second inlet of the PX, the PX exchanges pressure between the first fluid and the second fluid, the first fluid exits the PX through a first outlet of the PX at a third pressure, and the second fluid exits the PX through a second outlet of the PX at a fourth pressure.

20. The processing device is The non-temporary computer-readable recording medium according to claim 18, further comprising the operation of supplying the corresponding thermal energy from the fluid output from the turbine to the corresponding environment via a second heat exchanger configured to receive the fluid output from the turbine.

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