Systems for production of green hydrogen, electricity and heat

Abstract

A system includes a power generation sub-system configured to generate electrical energy, an electrolyzer configured to produce gaseous hydrogen responsive to receiving the electrical energy, and a heat pump sub-system configured to heat a process fluid. The power generation sub-system includes a first pressure exchanger (PX), a first heat exchanger, a turbine, and a generator. The heat pump sub-system includes a second heat exchanger, a third heat exchanger, and a second PX.

Description

SYSTEMS FOR PRODUCTION OF GREEN HYDROGEN, ELECTRICITY ANDHEATTECHNICAL FIELD

[0001] The present disclosure relates to pressure exchanger systems, and, more particularly, systems for production of green hydrogen, electricity, and heat.BACKGROUND

[0002] Systems use fluids at different pressures. Systems use pumps and / or compressors to increase pressure of fluid. Energy usage of a fluid handling system may be largely consumed by pumps and / or compressors increasing fluid pressure.BRIEF DESCRIPTION OF THE DRAWINGS

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

[0004] FIGS. 1A-D illustrate schematic diagrams of fluid handling systems including hydraulic energy transfer systems, according to certain embodiments.

[0005] FIGS. 2A-E are exploded perspective views of pressure exchangers (PXs), according to certain embodiments.

[0006] FIG. 3 is a simplified system diagram of a system having pressure exchangers for production of green hydrogen, electricity, and heat, according to certain embodiments.

[0007] FIGS. 4A-E are schematic diagrams of geothermal power generation sub-systems that each include a PX for use in a system for green hydrogen production, according to certain embodiments.

[0008] FIGS. 5A-C are schematic diagrams of heat pump sub-systems that each include a PX for use in a system for green hydrogen production, according to certain embodiments.

[0009] FIGS. 6A-D are schematic diagrams of systems having pressure exchangers for production of green hydrogen, electricity, and heat, according to certain embodiments.

[0010] FIG. 7 is a flow diagram illustrating an example method for an example system having pressure exchangers for production of green hydrogen, electricity, and heat , according to certain embodiments.

[0011] FIG. 8 is a block diagram illustrating a computer system, according to certain embodiments.DETAILED DESCRIPTION OF EMBODIMENTS

[0012] Embodiments described herein are related to systems for production of green hydrogen, geothermal electricity and heat (e.g., PX for green hydrogen applications). Green hydrogen (GH2) may be hydrogen produced by the electrolysis of water using renewal electricity, causing significantly lower greenhouse gas emissions than production of grey hydrogen derived from fossil fuels without carbon capture.

[0013] Systems may use fluids at different pressures. A supply of a fluid to a system may be at lower pressure, and one or more portions of the system may operate at higher pressures. A system may include a closed loop with various fluid pressures maintained in different portions of the loop. These systems may include hydraulic fracturing (e.g., fracking or fracing) systems, desalinization systems, refrigeration systems, heat pump systems, energy generation systems, mud pumping systems, slurry pumping systems, industrial fluid systems, waste fluid systems, fluid transportation systems, green hydrogen systems, etc. Pumps or compressors may be used to increase pressure of fluids of such systems. In some embodiments, such systems can be used in various capacities for producing products, such as hydrogen.

[0014] Hydrogen is an energy-dense material that can be used to satisfy energy needs in modem society. Hydrogen generally produces low and / or non-harmful emissions when burnt (e.g., hydrogen combustion). For example, unlike the combustion of natural gas or coal (which are common mechanisms of electricity generation today) which emits gases such as carbon dioxide (CO2) to the atmosphere, hydrogen combustion primarily produces water (e.g., water vapor). Hydrogen combustion may produce only trace amounts of nitrogen oxides (NOx) and / or carbon dioxide (CO2). The characteristics of the emissions from hydrogen combustion make hydrogen an attractive alternative to fossil fuels, such as for generating electricity. In addition, hydrogen can be used as an “energy storage” medium, such as where hydrogen can be produced when excess electricity is available. The produced hydrogen (e.g., produced using excess electricity) can be compressed and condensed into liquid form and stored in a pressure vessel. The stored liquid hydrogen can be transported for generating electricity (e.g., by combustion of the stored / transported hydrogen) at a later time.

[0015] However, hydrogen is commonly produced using energy-intense processes, such as electrolysis. Electrolysis is a process that uses electricity to split water (H2O) into its basic components: hydrogen (H2) and oxygen (O2). In this process, an electric current is passed through water, causing the water molecules to break apart at the electrodes. A system for performing electrolysis (e.g., an electrolyzer) involves two electrodes: an anode (positive)and cathode (negative), placed in water mixed with an electrolyte (such as potassium hydroxide or sulfuric acid) to improve conductivity. When electricity is applied to the anode and cathode, water molecules are reduced to form hydrogen gas (H2) and oxygen gas (O2). The hydrogen is captured and prepared for storage and / or transport.

[0016] Although hydrogen combustion has low and / or substantially non-harmful emissions, this advantage may be largely offset by the emissions of the process(es) used to produce the electricity used in hydrogen production. For example, where coal-fired power plants (and / or other fossil-fuel power plants that have high and / or harmful emissions, etc.) are used to produce the electricity for use in electrolysis, the sum-total emissions associated with the hydrogen (e.g., emissions associated with hydrogen production combined with the emissions from hydrogen combustion) is high. Therefore, using power plants which have high and / or harmful emissions to produce electricity for electrolysis may not be environmentally friendly, even when accounting for the low and / or non-harmful emissions from hydrogen combustion.

[0017] Hydrogen production can be considered “green” if the electricity used in electrolysis for producing the hydrogen comes from renewable sources such as wind, solar, hydro, or geothermal power. Wind and solar power sources can be unreliable because of the periodic nature of the source. For example, power can be extracted from wind only when the wind blows and solar power can be extracted only when the sun shines (e.g., during the daytime). For consistent energy needs (e.g., energy needs that substantially do not vary over time), geothermal power may be effective because geothermal power sources are always available (e.g., the geothermal source is active all the time, even at night, for example).

[0018] Conventionally, geothermal power systems (transfer heat from within the earth to the rest of the power generation system.. Conventional geothermal systems include systems that use heated fluid (e.g., hot water, hot brine, etc.) from a geothermal source (e.g., from within the Earth, a heated portion of the Earth, from a hot aquifer via a production well, etc.) to heat and / or evaporate fluid into vapor (e.g., steam, refrigerant gas, etc.). The vapor can be used to spin a turbine and the spinning turbine can then be used to generate electricity. Conventional geothermal power systems decrease the pressure of hot, high pressure geothermal fluid (e.g., hot water, hot brine, etc.) from a production well to a low pressure before introducing the hot geothermal fluid into a heat exchanger, where heat energy is extracted from the geothermal fluid and provided to the working fluid (e.g., water / steam, refrigerant, etc.) used in the turbine. The geothermal fluid is then reinjected into the ground (e.g., via a re-injection well into a hot aquifer). Re-injection of the geothermal fluid may beaccomplished using a re-injection pump that increases pressure of the geothermal fluid to high pressure for re-injection into the re-injection well.

[0019] Because of the low temperature of the geothermal fluid received from the production well relative to the operating temperatures of steam turbine systems powered by combustion (e.g., coal-fired steam turbines, etc.), conventional geothermal power generation systems have relatively low efficiency. For example, according to the Carnot efficiency (rimax = 1—maximum efficiency remains low when the hot source temperature (TH) is low. In some embodiments, the pressure energy of the geothermal fluid received from the production well in a geothermal power generation system can be extracted from the fluid and used to increase efficiency of the system, notwithstanding the low relative temperature of the hot geothermal fluid.

[0020] A geothermal well can be drilled deeper into the earth (e.g. 1 km to 7 km deep) to use heat from the hotter subsurface rock disposed at deeper depths within the earth. Often, the temperature of geothermal fluid coming out of a well is proportional to the depth of the well. For example, a deeper well may produce hotter fluid than a shallower well. Similarly, the pressure of geothermal fluid coming out of a well is proportional to the depth of the well. For example, a deeper well may produce higher pressure fluid than a shallower well. This phenomenon may be caused by increased geological formation pressure at deeper depths within the earth’s crust (e.g., pressure due to weight of the rocks and soil above as well as that due to the pressure of the fluid in the pore spaces of the rocks beneath the earth’s surface). Therefore, if a geothermal well is drilled deeper to obtain higher temperature of the geothermal fluid (e.g., such as for a power generation cycle), it often follows that the geothermal fluid coming out of the well will also have an increased pressure.

[0021] Conventional systems may not be capable of utilizing the pressure energy of the high pressure geothermal fluid. Some conventional systems may only utilize the heat energy of the geothermal fluid. The heat energy may be extracted in a heat exchanger. The heat energy may be transferred to the working fluid of an associated power generation system ( e.g. such as steam, CO2, or organic Rankine cycle fluid, etc.). Some heat exchangers may be designed to operate at lower pressure. Therefore, some systems decrease pressure of the geothermal fluid before the geothermal fluid enters the heat exchanger. Some systems decrease pressure of the geothermal fluid by using a pressure valve upstream of the heat exchanger. Decreasing the pressure of the geothermal fluid may waste much of the usefulpressure energy of the geothermal fluid that could have otherwise been harnessed / extracted to do useful work.

[0022] In some embodiments systems described in the present disclosure extract pressure energy of the geothermal fluid and use the extracted pressure energy to compress the working fluid of the power generation system to high pressure or to pump the geothermal fluid back to high pressure after heat from the geothermal fluid has been extracted (e.g., in a heat exchanger), in some embodiments, by compressing the working fluid of the power generation system using the pressure of the geothermal fluid, the PX decreases the energy consumed by the compressor of the power generation system, thus making the power generation system more efficient while also producing more net electricity. In some embodiments, by increasing pressure of the low pressure geothermal fluid to high pressure (e.g., for re-injection to the geothermal source), the PX reduces the energy used by the re-injection pump to re-inject the geothermal fluid into the re-injection well, thus increasing the efficiency of the geothermal power generation system. In some embodiments, the systems described herein provide a more efficient geothermal power generation system than conventional systems. Therefore, hydrogen production using systems described herein may be more efficient than conventional systems.

[0023] A byproduct of hydrogen production using electrolysis is waste heat. Conventionally, the waste heat is not captured and is allowed to escape to the ambient environment. The waste heat from electrolysis may be a low grade heat, meaning the heat may be a low temperature heat and / or may not be useful. However, if the waste heat from electrolysis is upgraded, such as with a heat pump in some embodiments, the upgraded heat (e.g., higher temperature heat) can be used, such as for building heating, district heating, and / or for industrial process heating applications ( e.g. dairy processing, meat processing, paper production, petrochemical processing, cement production, etc.). In some embodiments, systems use the waste heat from hydrogen production efficiently. Conventionally, heat transfer systems (e.g., refrigeration systems, heat pump systems, reversible heat pump systems, or the like, etc.) use pumps and / or compressors to increase the pressure and / or temperature of a fluid (e.g., a refrigeration fluid such as carbon dioxide (CO2), R-134a, R- 404a, R-410a, R-454b, R-744, hydrocarbons, propane , butane, hydrofluorocarbons (HFCs), hydrochlorofluorocarbons (HCFCs), ammonia (NH3), refrigerant blends, R-407A, R-404A, etc.). Conventionally, separate pumps and / or compressors are used to increase pressure of the fluid in any portion of a system including an increase in fluid pressure. Pumps and / or compressors, especially those that operate over a large pressure differential (e.g., cause alarge pressure increase in the fluid), require large quantities of energy. Conventional systems thus expend large amounts of energy increasing the pressure of the fluid (via the pumps and / or compressors that can be driven by motors). Additionally, conventional fluid transfer systems decrease the pressure of the fluid through expansion valves. Conventional systems inefficiently increase pressure of fluid and decrease pressure of the fluid (e.g., when operating in a loop). This is wasteful in terms of energy used to run the conventional systems (e.g., energy used to repeatedly increase the pressure of the refrigeration fluid to cause increase or decrease of temperature of the surrounding environment). In some embodiments, a heat pump system includes a pressure exchanger (PX). that the heat pump system may upgrade the low temperature heat (e.g., low grade heat) from a hydrogen-producing electrolyzer to a higher temperature (e.g., a high grade heat) while consuming less electrical energy than traditional systems. In some embodiments, the PX uses high pressure refrigerant fluid (e.g., high pressure liquid refrigerant, high pressure supercritical state refrigerant, etc.) to compress low pressure refrigerant (e.g., low pressure refrigerant vapor) . In some embodiments, the PX reduces the energy consumed by the compressor of the heat pump system, thus increasing the efficiency of the heat pump system.

[0024] In some embodiments, capturing the low grade heat (e.g., low temperature heat) from the exhaust of the geothermal power generation turbine and from the hydrogen electrolyzer, and upgrading the captured low grade heat reduces the total energy consumption for the end-use heating and / or industrial process. Therefore, a combined system having a geothermal power generation sub-system and a heat pump sub-system using waste heat from hydrogen production may be more efficient than these individual sub-systems operating separately.

[0025] The systems, devices, and methods of the present disclosure provide fluid handling systems (e.g., for geothermal energy production, for electricity production, for hydrogen production, for heat pumping, for heating, etc.) that include pressure exchangers (PXs). In some embodiments, a system includes a power generation sub-system, an electrolyzer, and a heat pump sub-system. In some embodiments, the power generation sub-system may extract energy associated with pressure from the geothermal fluid (e.g., hot water, hot brine, etc.) and may further extract energy associated with heat from the geothermal fluid. The extracted energy may be used to generate electricity, such as by using a turbine and a generator, etc. In some embodiments, the electrolyzer may be powered by the electricity produced by the power generation sub-system, such as to produce hydrogen. In some embodiments, the heat pump sub-system may heat a process fluid using excess thermal energy (e.g., excess heat)from the electrolyzer. The process fluid may be used in a process otherwise unrelated to the power generation sub-system, the electrolyzer, and / or the heat pump sub-system. For example, the heated process fluid may be used for heating a building, for district heating applications, for producing steam, and / or for providing industrial process heat (e.g., such as in dairy, meat, or paper industries, etc.)or used for another suitable process, etc.

[0026] The power generation sub-system and the heat pump sub-system may each include a PX that is configured to exchange pressure between corresponding fluids. In some embodiments, the PX of the power generation sub-system exchanges pressure between the geothermal fluid and the working fluid of the power generation sub-system (e.g., the fluid used in the turbine). The power generation sub-system may further include a heat exchanger to exchange thermal energy between the geothermal fluid and the working fluid. The PX and the heat exchanger of the power generation sub-system may enable extraction of the pressure energy and the heat energy from the geothermal fluid respectively. In some embodiments, the PX of the heat pump sub-system exchanges pressure between high pressure and low pressure portions of working fluid (e.g., refrigeration fluid) in a heat pump cycle. The working fluid of the heat pump sub-system may be separate from the working fluid of the power generation sub-system. In some embodiments, each PX (of the respective sub-systems) receives high pressure fluid at a first pressure via a first inlet (e.g., a high pressure inlet) and low pressure fluid at a second pressure via a second inlet (e.g., a low pressure inlet). The first pressure may be higher than the second pressure. Each PX may exchange pressure between the high pressure fluid and the low pressure fluid, effectively converting the low pressure fluid to high pressure fluid and the high pressure fluid to low pressure fluid. The converted low pressure fluid may exit the PX at a third pressure via a first outlet (e.g., a low pressure outlet) and the converted high pressure fluid may exit the PX at a fourth pressure via a second outlet (e.g., a high pressure outlet). The third pressure may be lower than the fourth pressure.

[0027] Further details for the system(s) and / or sub-systems are described herein below with respect to the figures.

[0028] The systems, devices, and methods of the present disclosure have advantages over conventional solutions. According to embodiments described herein, “green” hydrogen may be produced. That is, hydrogen may be produced without excessive and / or harmful emissions characteristic of fossil-fuel-powered electricity generation systems. Moreover, the efficiency of hydrogen production may be increased by using geothermal power generation sub-systems to generate electricity used for hydrogen production as described herein. Additionally, the geothermal power generation sub-systems of the present disclosure may have an increasedefficiency when compared to conventional systems. For example, the systems described herein extract both energy associated with heat and energy associated with pressure from the geothermal fluid received from the geothermal source (e.g., below ground) to increase temperature and pressure of a working fluid to drive a turbine. In some embodiments, by using a PX in the power generation sub-system, the systems described herein reduce energy consumed to increase pressure of a working fluid (e.g., to a supercritical state) to drive a turbine. Additionally, waste heat (e.g., from the electrolyzer) otherwise not captured in conventional systems may be used to heat a process fluid, via a heat pump sub-system, thus increasing the overall efficiency of the system. In some embodiments, by using a PX in the heat pump sub-system, the systems described herein reduce energy consumed to increase pressure of working fluid (e.g., refrigerant) used in the heat pump sub-system. Reduced energy consumption can lead to increased cost effectiveness and / or reduced environmental impact, particularly over the life of the system.

[0029] Although some embodiments of the present disclosure are described in relation to pressure exchangers, energy recovery devices, and hydraulic energy transfer systems, the current disclosure can be applied to other systems and devices (e.g., pressure exchanger that is not isobaric, rotating components that are not a pressure exchanger, a pressure exchanger that is not rotary, systems that do not include pressure exchangers, etc.).

[0030] Although some embodiments of the present disclosure are described in relation to exchanging pressure between fluid used in geothermal power generation systems, heat pump systems, and / or refrigeration systems, the present disclosure can be applied to other types of systems. Fluids can refer to liquid, gas, transcritical fluid, supercritical fluid, subcritical fluid, and / or combinations thereof.

[0031] Although some embodiments of the present disclosure are described in relation to receiving hot, high pressure fluid (e.g., brine and / or water) from the ground (e.g., hot aquifer), the present disclosure can receive other types of fluids (e.g., lower temperature, lower pressure, etc.) from the ground (e.g., below ground surface level).

[0032] Although some embodiments of the present disclosure are described in relation to receiving fluid from a hot source (e.g., hot aquifer) below the ground surface, the present disclosure can receive fluid from other sources (e.g., environmental ground temperature) below the ground surface.

[0033] FIG. 1A illustrates a schematic diagram of a fluid handling system 100 A that includes a hydraulic energy transfer system 110, according to certain embodiments.

[0034] In some embodiments, a hydraulic energy transfer system 110 includes a pressure exchanger (e.g., PX). The hydraulic energy transfer system 110 (e.g., PX) receives low pressure (LP) fluid in 120 (e.g., via a low-pressure inlet) from an LP in system 122. The hydraulic energy transfer system 110 also receives high pressure (HP) fluid in 130 (e.g., via a high-pressure inlet) from HP in system 132. In some embodiments, HP in system 132 includes a source of hot, high pressure geothermal fluid (e.g., a hot aquifer, a geothermal production well, etc.). The hydraulic energy transfer system 110 (e.g., PX) exchanges pressure between the HP fluid in 130 and the LP fluid in 120 to provide LP fluid out 140 (e.g., via low-pressure outlet) to LP fluid out system 142 and to provide HP fluid out 150 (e.g., via high-pressure outlet) to HP fluid out system 152. In some embodiments, HP fluid out system 152 includes a turbine (e.g., as part of a power cycle) to recover energy from HP fluid out 150. A controller 180 may cause an adjustment of flowrates of HP fluid in 130 and LP fluid out.

[0035] In some embodiments, the hydraulic energy transfer system 110 includes a PX to exchange pressure between the HP fluid in 130 and the LP fluid in 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 HP fluid in 130 and LP fluid in 120 at efficiencies (e.g., pressure transfer efficiencies, substantially isobaric) in excess of approximately 50%, 60%, 70%, 80%, 90%, or greater (e.g., without utilizing centrifugal technology). High pressure (e.g., HP fluid in 130, HP fluid out 150) refers to pressures greater than the low pressure (e.g., LP fluid in 120, LP fluid out 140). LP fluid in 120 of the PX may be pressurized and exit the PX at high pressure (e.g., HP fluid out 150, at a pressure greater than that of LP fluid in 120), and HP fluid in 130 may be depressurized and exit the PX at low pressure (e.g., LP fluid out 140, at a pressure less than that of the HP fluid in 130). The PX may operate with the HP fluid in 130 directly applying a force to pressurize the LP fluid in 120, with or without a fluid separator between the fluids. Examples of fluid separators that may be used with the PX include, but are not limited to, pistons, bladders, diaphragms and the like. In some embodiments, PXs may be rotary devices. Rotary PXs, such as those manufactured by Energy Recovery, Inc. of San Leandro, Calif., may not have any separate valves, since the effective valving action is accomplished internal to the device via the relative motion of a rotor with respect to end covers. Rotary PXs may be designed to operate with internal pistons to isolate fluids and transfer pressure with relatively little mixing of the inlet fluid streams. Reciprocating PXs may include a piston moving back and forth in a cylinder for transferring pressure between the fluid streams. Any PX ormultiple PXs may be used in the present disclosure, such as, but not limited to, rotary PXs, reciprocating PXs, or any combination thereof. In addition, the PX may be disposed on a skid separate from the other components of a fluid handling system 100 (e.g., in situations in which the PX is added to an existing fluid handling system). For example, the PX may be fastened to a structure that can be moved from one site to another. The PX may be coupled to a system (e.g., pipes of a system, etc.) that has been built on-site. The structure to which the PX is fastened may be referred to as a ‘skid.’

[0036] In some embodiments, a motor 160 is coupled to hydraulic energy transfer system 110 (e.g., to a PX). In some embodiments, the motor 160 controls the speed (e.g., rotational speed, rotational velocity, angular velocity, etc.) of a rotor of the hydraulic energy transfer system 110 (e.g., to increase pressure of HP fluid out 150, to decrease pressure of HP fluid out 150, etc.). In some embodiments, motor 160 generates energy (e.g., acts as a generator) based on pressure exchanging in hydraulic energy transfer system 110.

[0037] The hydraulic energy transfer system 110 may include a hydraulic turbocharger or hydraulic pressure exchanger, such as a rotating PX. The PX may include one or more chambers (e.g., 1 to 100) to facilitate pressure transfer between first and second fluids (e.g., gas, liquid, multi-phase fluid). In some embodiments, the PX may transfer pressure between a first fluid (e.g., pressure exchange fluid, such as a proppant free fluid, substantially proppant free fluid, lower viscosity fluid, fluid that has lower than a threshold amount of certain chemicals, non-caustic fluid, non-acidic fluid, etc.) and a second fluid that may have a higher viscosity (e.g., be highly viscous), include more than a threshold amount of certain chemicals (e.g., a caustic fluid, an acidic fluid, etc.), and / or contain solid particles (e.g., geothermal fluid, frac fluid containing sand, proppant, powders, debris, ceramics, etc.).

[0038] Fluid handling system 100 A may additionally include one or more sensors to provide sensor data (e.g., flowrate data, pressure data, velocity data, etc.) associated with the fluids of fluid handling system 100 A. Controller 180 may control one or more flow rates of fluid handling system 100 A based on the sensor data. In some embodiments, controller 180 causes one or more flow valves to actuate based on sensor data received. In some embodiments, the controller 180 can perform the method of FIG. 9.

[0039] One or more components of the hydraulic energy transfer system 110 may be used in different types of systems, such as geothermal power generation systems, fracing systems, desalination systems, refrigeration and heat pump systems, slurry pumping systems, industrial fluid systems, waste fluid systems, fluid transportation systems, heat transfer systems, etc.

[0040] FIG. IB illustrates a schematic diagram of a fluid handling system 100B including a hydraulic energy transfer system 110, according to certain embodiments. Fluid handling system 100B may be a geothermal power generation system (e.g., a geothermal power generation sub-system). In some embodiments, fluid handling system 100B includes more components, less components, same routing, different routing, and / or the like than that shown in FIG. IB. Some of the features in FIG. IB that have similar reference numbers as those in FIG. 1 A may have similar properties, functions, and / or structures as those in FIG. 1 A.

[0041] HP fluid in 130 and LP fluid out 140 may be geothermal fluid (e.g., particlecontaining fluid, hot water, hot geothermal brine, etc.). LP fluid in 120 and HP fluid out 150 may be process fluid (e.g., proppant free fluid, water, filtered fluid, CO2, supercritical CO2, hydrofluorocarbons such as R134a, R245fa, hydrocarbons such as isobutene, pentane, propane, etc.).

[0042] LP in system 122 may include one or more low pressure fluid pumps and / or compressors to provide LP fluid in 120 to the hydraulic energy transfer system 110 (e.g., PX). HP in system 132 may include a hot aquifer 134 to provide HP fluid in 130 to hydraulic energy transfer system 110. In some embodiments, HP fluid in 130 is received by the hydraulic energy transfer system 110 via a production well in fluid communication with the hot aquifer 134. Controller 180 may control one or more components of fluid handling system 100B.

[0043] Hydraulic energy transfer system 110 exchanges pressure between LP fluid in 120 (e.g., low pressure process fluid, low pressure CO2, etc.) and HP fluid in 130 (e.g., high pressure geothermal fluid, high pressure hot water, etc.) to provide HP fluid out 150 (e.g., high pressure process fluid, high pressure CO2, etc.) to HP out system 152 and to provide LP fluid out 140 (e.g., low pressure geothermal fluid, low pressure hot water, etc.) to LP out system 142. In some embodiments, HP out system 152 includes a turbine 129 to receive the HP fluid out 150. The turbine 129 may convert thermal energy in HP fluid out 150 into kinetic energy and provide fluid to the LP in system 122. The turbine 129 may be mechanically coupled to a generator to produce electricity. In some embodiments, the fluid from the turbine 129 is cooled in a gas cooler 118 of the LP in system 122 to form LP fluid in 120. In some embodiments, LP fluid out 140 is provided to a heat exchanger to exchange thermal energy (e.g., exchange heat, provide heat, etc.) with HP fluid out 150. Heated HP fluid 150 may be provided to the turbine 129. Cooled LP fluid out 140 may be provided to HP in system 132 by reinjection into the hot aquifer 134 (e.g., via a reinjection well). Inalternative embodiments, HP fluid out 150 is geothermal fluid and is provided from the hydraulic energy transfer system 110 to a reinjection well of the hot aquifer 134.

[0044] Fluid handling system 100B may additionally include one or more sensors configured to provide sensor data associated with the fluid. One or more flow valves may control flowrates of the fluid based on sensor data received from the one or more sensors. In some embodiments, controller 180 causes one or more flow valves (not illustrated) to actuate based on sensor data received.

[0045] FIG. 1C illustrates a schematic diagram of a fluid handling system 100C including a hydraulic energy transfer system 110, according to certain embodiments. Fluid handling system 100C may be a refrigeration system or a heat pump system. In some embodiments, fluid handling system 100C is a thermal energy (e.g., heat) transport system (e.g., heat transport system, thermal transport system). Fluid handling system 100C may be configured to cool and / or heat an environment (e.g., an indoor space, a refrigerator, a freezer, etc.) and / or a process fluid. In some embodiments, fluid handling system 100C includes more components, less components, same routing, different routing, and / or the like than that shown in FIG. 1C. Some of the features in FIG. 1C that have similar reference numbers as those in FIGS. 1 A and / or IB may have similar properties, functions, and / or structures as those in FIG. 1 A and / or IB.

[0046] Hydraulic energy transfer system 110 (e.g., PX) may receive LP fluid in 120 from LP in system 122 (e.g., low pressure lift device 128, low pressure fluid pump, low pressure booster, low pressure compressor, low pressure ejector, etc.) and HP fluid in 130 from HP in system 132 (e.g., condenser 137, gas cooler, heat exchanger, etc.). The hydraulic energy transfer system 110 (e.g., PX) may exchange pressure between the LP fluid in 120 and HP fluid in 130 to provide HP fluid out 150 to HP out system 152 (e.g., high pressure lift device 159, high pressure fluid pump, high pressure booster, high pressure compressor, high pressure ejector, etc.) and to provide LP fluid out 140 to LP out system 142 (e.g., evaporator 144, heat exchanger, receiver 113, etc.). The LP out system 142 (e.g., evaporator 144, receiver 113) may provide the fluid to compressor 178 and low pressure lift device 128. The evaporator 144 may provide the fluid to compressor 178 and the receiver 113 (e.g., flash tank) may provide fluid to the low pressure lift device 128. The condenser 137 may receive fluid from compressor 178 and high pressure lift device 159. Controller 180 may control one or more components of fluid handling system 100C. High pressure lift device 159 may be a high pressure booster and low pressure lift device 128 may be a low pressure booster.

[0047] The fluid handling system 100C may be a closed system. LP fluid in 120, HP fluid in 130, LP fluid out 140, and HP fluid out 150 may all be a fluid (e.g., refrigerant, the same fluid) that is circulated in the closed system of fluid handling system 100C.

[0048] Fluid handling system 100C may additionally include one or more sensors configured to provide sensor data associated with the fluid. One or more flow valves may control flowrates of the fluid based on sensor data received from the one or more sensors. In some embodiments, controller 180 causes one or more flow valves (not illustrated) to actuate based on sensor data received.

[0049] FIG. ID illustrates a schematic diagram of a fluid handling system 100D including a hydraulic energy transfer system 110, according to certain embodiments. In some embodiments, fluid handling system 100D is a thermal energy (e.g., heat) transport system (e.g., heat handling system, thermal transport system). Fluid handling system 100D may be a heat pump system or a refrigeration system. Fluid handling system 100D may be configured to heat and / or cool an environment (e.g., an indoor space, a refrigerator, a freezer, etc.). In some embodiments, fluid handling system 100D includes more components, less components, same routing, different routing, and / or the like than that shown in FIG. ID. Some of the features in FIG. ID that have similar reference numbers as those in FIGS. 1 A, IB, and / or 1C may have similar properties, functions, and / or structures as those in FIGS. 1 A, IB, and / or 1C.

[0050] Hydraulic energy transfer system 110 (e.g., PX) may receive LP fluid in 120 from LP in system 122 (e.g., low pressure lift device 114, low pressure fluid pump, low pressure booster, low pressure compressor, etc.) and HP fluid in 130 from HP in system 132 (e.g., gas cooler 138, gas cooler, heat exchanger, etc.). The hydraulic energy transfer system 110 (e.g., PX) may exchange pressure between the LP fluid in 120 and HP fluid in 130 to provide HP fluid out 150 to HP out system 152 (e.g., high pressure lift device 159, high pressure fluid pump, high pressure booster, high pressure compressor, etc.) and to provide LP fluid out 140 to LP out system 142 (e.g., evaporator 144, heat exchanger, receiver 113, etc.). The LP out system 142 (e.g., evaporator 144) may provide the fluid to compressor 178 and low pressure lift device 114. The gas cooler 138 may receive fluid from compressor 178 and high pressure lift device 159. The gas cooler 138 may provide thermal energy from the fluid to another fluid such as a process fluid 127 (e.g., steam, etc.). The heated process fluid 127 may be used in another process, such as a heating process (e.g., for heating a building, etc.) or another suitable process. Controller 180 may control one or more components of fluid handlingsystem 100D. High pressure lift device 159 may be a high pressure booster and low pressure lift device 114 may be a low pressure booster.

[0051] The fluid handling system 100D may be a closed system. LP fluid in 120, HP fluid in 130, LP fluid out 140, and HP fluid out 150 may all be a fluid (e.g., refrigerant, the same fluid) that is circulated in the closed system of fluid handling system 100D.

[0052] Fluid handling system 100D may additionally include one or more sensors configured to provide sensor data associated with the fluid. One or more flow valves may control flowrates of the fluid based on sensor data received from the one or more sensors. In some embodiments, controller 180 causes one or more flow valves (not illustrated) to actuate based on sensor data received.

[0053] FIGS. 2A-E are exploded perspective views a rotary PX 40 (e.g., rotary pressure exchanger, rotary liquid piston compressor (LPC)), according to certain embodiments. Some of the features in one or more of FIGS. 2A-E may have similar properties, functions, and / or structures as those in one or more of FIGS. 1A-D.

[0054] 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, acidic fluid, frac fluid, superheated gaseous carbon dioxide, refrigerant, HP fluid in 130, etc.) and a second fluid (e.g., geothermal fluid, process fluid, particle free fluid, non-caustic fluid, non-acidic fluid, proppant free fluid or supercritical carbon dioxide, refrigerant, LP fluid in 120, etc.) with minimal mixing of the fluids. The rotary PX 40 may include a generally cylindrical body portion 42 that includes a sleeve 44 (e.g., rotor sleeve) and a rotor 46. The rotary PX 40 may also include two end caps 48 and 50 that include manifolds 52 and 54, respectively. Manifold 52 includes respective inlet port 56 and outlet port 58, while manifold 54 includes respective inlet port 60 and outlet port 62. In operation, these inlet ports 56, 60 enable the first and second fluids to enter the rotary PX 40 to exchange pressure, while the outlet ports 58, 62 enable the first and second fluids to then exit the rotary PX 40. In operation, the inlet port 56 may receive a high-pressure first fluid (e.g., HP fluid in 130), and after exchanging pressure, the outlet port 58 may be used to route a low-pressure first fluid (e.g., LP fluid out 140) out of the rotary PX 40. Similarly, the inlet port 60 may receive a low-pressure second fluid (e.g., low pressure slurry fluid, LP fluid in 120) and the outlet port 62 may be used to route a high- pressure second fluid (e.g., high pressure slurry fluid, HP fluid out 150) out of the rotary PX 40. The end caps 48 and 50 include respective end covers 64 and 66 (e.g., end plates) disposed within respective manifolds 52 and 54 that enable fluid sealing contact with the rotor 46.

[0055] One or more components of the PX 40, such as the rotor 46, the end cover 64, and / or the end cover 66, may be constructed from a wear-resistant material (e.g., carbide, cemented carbide, silicon carbide, tungsten carbide, etc.) with a hardness greater than a predetermined threshold (e.g., a Vickers hardness number that is at least 1000, 1250, 1500, 1750, 2000, 2250, or more). For example, tungsten carbide may be more durable and may provide improved wear resistance to abrasive fluids as compared to other materials, such as alumina ceramics. Additionally, in some embodiments, one or more components of the PX 40, such as the rotor 46, the end cover 64, the end cover 66, and / or other sealing surfaces of the PX 40, may include an insert. In some embodiments, the inserts may be constructed from one or more wear-resistant materials (e.g., carbide, cemented carbide, silicon carbide, tungsten carbide, etc.) with a hardness greater than a predetermined threshold (e.g., a Vickers hardness number that is at least 1000, 1250, 1500, 1750, 2000, 2250, or more) to provide improved wear resistance.

[0056] The rotor 46 may be cylindrical and disposed in the sleeve 44, which enables the rotor 46 to rotate about the axis 68. The rotor 46 may have a plurality 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 arranged symmetrically about the longitudinal axis 68. The openings 72 and 74 of the rotor 46 are arranged for hydraulic communication with inlet and outlet apertures 76 and 78 (e.g., end cover inlet port and end cover outlet port) and 80 and 82 (e.g., end cover inlet port and end cover outlet port) in the end covers 64 and 66, in such a manner that during rotation the channels 70 are exposed to fluid at high-pressure and fluid at low-pressure. As illustrated, the inlet and outlet apertures 76 and 78 and 80 and 82 may be designed in the form of arcs or segments of a circle (e.g., C-shaped).

[0057] In some embodiments, a controller (e.g., controller 180 of FIGS. 1A-D) using sensor data (e.g., revolutions per minute measured through a tachometer or optical encoder or volumetric flow rate measured through flowmeter) may control the extent of mixing between the first and second fluids in the rotary PX 40, which may be used to improve the operability of the fluid handling system (e.g., fluid handling systems 100A-B of FIGS. 1A-D). In some examples, varying the volumetric flow rates of the first and / or second fluids entering the rotary PX 40 allows the operator (e.g., system operator, plant operator) to control the amount of fluid mixing within the PX 40. In addition, varying the rotational speed (e.g., rotational velocity) of the rotor 46 (e.g., via a motor) also allows the operator to control mixing. Three characteristics of the rotary PX 40 that affect mixing are: (1) the aspect ratio of the rotor channels 70; (2) the duration of exposure between the first and second fluids; and (3) thecreation of a fluid barrier (e.g., an interface) between the first and second fluids within the rotor channels 70. First, the rotor channels 70 (e.g., ducts) are generally long and narrow, which stabilizes the flow within the rotary PX 40. In addition, the first and second fluids may move through the channels 70 in a plug flow regime 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., rotor speed of approximately 1200 revolutions per minute (RPM)) may reduce contact times between the first and second fluids to less than approximately 0.15 seconds, 0.10 seconds, or 0.05 seconds. Third, a small portion of the rotor channel 70 is used for the exchange of pressure between the first and second fluids. Therefore, a volume of fluid remains in the channel 70 as a barrier between the first and second fluids. All these mechanisms may limit mixing within the rotary PX 40. Moreover, in some embodiments, the rotary PX 40 may be designed to operate with internal pistons or other barriers (e.g., physical barrier), either complete or partial, that isolate the first and second fluids while enabling pressure transfer.

[0058] FIGS. 2B-2E are exploded views of an embodiment of the rotary PX 40 illustrating the sequence of positions of a single rotor channel 70 in the rotor 46 as the channel 70 rotates through a complete cycle. It is noted that FIGS. 2B-2E are simplifications of the rotary PX 40 showing one rotor channel 70, and the channel 70 is shown as having a circular cross- sectional shape. In other embodiments, the rotary PX 40 may include a plurality of channels 70 with the same or different cross-sectional shapes (e.g., circular, oval, square, rectangular, polygonal, etc.). Thus, FIGS. 2B-2E are simplifications for purposes of illustration, and other embodiments of the rotary PX 40 may have configurations different from those shown in FIGS. 2A-2E. As described in detail below, the rotary PX 40 facilitates pressure exchange between first and second fluids (e.g., a hot geothermal fluid and a process fluid) by enabling the first and second fluids to briefly contact each other within the rotor 46. In some embodiments, the PX facilitates pressure exchange between first and second fluids by enabling the first and second fluids to contact opposing sides of a barrier (e.g., a reciprocating barrier, a piston, not shown). In certain embodiments, this exchange happens at speeds that result in limited mixing of the first and second fluids. The speed of the pressure wave traveling through the rotor channel 70 (as soon as the channel is exposed to the aperture 76), the diffusion speeds of the fluids, and / or the rotational speed of rotor 46 may dictate whether any mixing occurs and to what extent.

[0059] FIG. 2B is an exploded perspective view of an embodiment of a rotary PX 40 (e.g., rotary LPC), according to certain embodiments. In FIG. 2B, the channel opening 72 is in afirst position. In the first position, the channel opening 72 is in fluid communication with the aperture 78 in end cover 64 and therefore with the manifold 52, while the opposing channel opening 74 is in hydraulic communication with the aperture 82 in end cover 66 and by extension with the manifold 54. The rotor 46 may rotate in the clockwise direction indicated by arrow 84. In operation, low-pressure second fluid 86 (e.g., low pressure slurry fluid) passes through end cover 66 and enters 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 out of the channel 70, through end cover 64, and out of the rotary PX 40. However, because of the short duration of contact, there is minimal mixing between the second fluid 86 (e.g., slurry fluid) and the first fluid 88 (e.g., particulate-free fluid). In some embodiments, low pressure second fluid 86 contacts a first side of a barrier (e.g., a piston, not shown) disposed in channel 70 that is in contact (e.g., on an opposing side of the barrier) by first fluid 88. The second fluid 86 drives the barrier which pushes 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.

[0060] FIG. 2C is an exploded perspective view of an embodiment of a rotary PX 40 (e.g., rotary LPC), according to certain embodiments. In FIG. 2C, the channel 70 has 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 end cover 66, and the opening 72 is no longer in fluid communication with the apertures 76 and 78 of end cover 64. Accordingly, the low-pressure second fluid 86 is temporarily contained within the channel 70.

[0061] FIG. 2D is an exploded perspective view of an embodiment of a rotary PX 40 (e.g., rotary LPC), according to certain embodiments. In FIG. 2D, the channel 70 has rotated through approximately 60 degrees of arc from the position shown in FIG. 2B. The opening 74 is now in fluid communication with aperture 80 in end cover 66, and the opening 72 of the channel 70 is now in fluid communication with aperture 76 of the end cover 64. In this position, high-pressure first fluid 88 enters and pressurizes the low-pressure second fluid 86, driving the second fluid 86 out of the rotor channel 70 and through the aperture 80.

[0062] FIG. 2E is an exploded perspective view of an embodiment of a rotary PX 40 (e.g., rotary LPC), according to certain embodiments. In FIG. 2E, the channel 70 has rotated through approximately 270 degrees of arc 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 of end cover 66, and the opening 72 is no longer in fluid communication with the apertures 76 and 78 of end cover 64. Accordingly, the first fluid 88 is no longer pressurized and istemporarily contained within the channel 70 until the rotor 46 rotates another 90 degrees, starting the cycle over again.

[0063] FIG. 3 is a simplified system diagram of a green hydrogen pressure exchanger system 300, according to certain embodiments. In some embodiments, system 300 includes a geothermal power generation sub-system 310 (e.g., that includes a PX), an electrolyzer 320, and a heat pump sub-system 330. The geothermal power generation sub-system 310 receives input geothermal fluid 302. The fluid 302 may be a geothermal fluid, such as water and / or brine. The fluid 302 may be received from a geothermal source 301, such as a geothermal production well. In some embodiments, the fluid 302 is at high pressure and / or at high temperature. Using a PX, the geothermal power generation sub-system 310 may extract energy associated with pressure from the fluid 302. Using a heat exchanger, the geothermal power generation sub-system 310 may extract energy associated with heat from the fluid 302. In some embodiments, the extracted energy is provided to a working fluid in the geothermal power generation sub-system 310 to power a turbine. The turbine may convert the provided energy (extracted from the geothermal fluid 302) into rotational kinetic energy. An electrical generator may be mechanically coupled with the turbine and may convert the rotational kinetic energy into electrical energy (e.g., electricity 312). The output geothermal fluid 304 may be provided back to the geothermal source 301, such as by a re-injection well.

[0064] The electrical energy (e.g., electricity 312) produced by the geothermal power generation sub-system 310 may be used to power the electrolyzer 320. In some embodiments, the electrolyzer 320 is electrically coupled with the generator of the geothermal power generation sub-system 310. The electricity 312 may be provided to the electrodes of the electrolyzer 320. The electrodes may be disposed in water (e.g., pure water). The water may be mixed with an electrolyte. Responsive to being powered with electricity 312, the electrolyzer 320 may produce hydrogen 322. In some embodiments, the hydrogen 322 is captured and prepared for storage and / or transport. For example, the hydrogen 322 may be compressed (e.g., by a compressor) and stored in storage tank(s).

[0065] The electrolyzer 320 may produce excess heat 324. In some embodiments, the excess heat 324 is provided from the electrolyzer to the heat pump sub-system 330. One or more heat exchangers may enable the transfer of the excess heat 324 from the electrolyzer 320 to the heat pump sub-system 330. In some embodiments, the heat pump sub-system 330 receives a cold process fluid 332. Using the excess heat 324 and one or more heat exchangers, the heat pump sub-system 330 may heat the cold process fluid 332 to produceheated process fluid 334. In some embodiments, the heat pump sub-system 330 includes a PX to increase the efficiency of the heat pump cycle.

[0066] FIGS. 4A-E are schematic diagrams of geothermal power generation sub-systems 400A-D that each include a PX for use in a system for green hydrogen production, according to certain embodiments. Some of the features in one or more of FIGS. 4A-D may have similar properties, functions, and / or structures as those in one or more of FIGS. 1 A-D, FIGS. 2A-E, and / or FIG. 3.

[0067] FIG. 4A is a schematic diagram of a geothermal power generation sub-system 400A including a pressure exchanger (PX) 410, according to certain embodiments. PX 410 may be a rotary pressure exchanger. In some embodiments, PX 410 is an isobaric or substantially isobaric pressure exchanger. In some embodiments, PX 410 is coupled to a motor. Rotation of the rotor (e.g., rotational velocity of the rotor) of PX 410 may be controlled by the motor.

[0068] In some embodiments, system 400A includes a high pressure (HP) source (e.g., HP in system 132 of one or more of FIGS. 1 A-D). The HP source may be a source of a high pressure and / or high temperature fluid, such as a geothermal fluid (e.g., water, brine, etc.). In some embodiments, the HP source is a hot aquifer 434. Hot aquifer 434 may be an underground source of hot fluid. In some embodiments, a production well 402 in fluid communication with the hot aquifer 434 and drilled through the subsurface rock provides hot, high pressure geothermal fluid (e.g., brine and / or water). In some embodiments, geothermal fluid is provided at a pressure between about 150 bar and about 250 bar and at a temperature between about 60 degrees Celsius (°C) and about 500°C. Hot, high pressure geothermal fluid may flow from the production well 402 to the high pressure inlet of the PX 410. In some embodiments, the PX 410 exchanges pressure between the high pressure geothermal fluid and low pressure geothermal fluid to increase pressure of the low pressure geothermal fluid for re-injection of the geothermal fluid into the hot aquifer 434 via the re-injection well 404. In some embodiments, such as illustrated in FIGS. 4B and 4C, the PX 410 exchanges pressure between the high pressure geothermal fluid and a process fluid (such as CO2, hydrofluorocarbons such as R134a, R245fa, hydrocarbons such as isobutene, pentane, propane, power cycle fluid, etc.) used for driving the turbine 428.

[0069] In some embodiments, the PX 410 receives the high pressure geothermal fluid via a high pressure inlet (e.g., HPin) and receives the low pressure geothermal fluid via a low pressure inlet (e.g., LPin). Although there is a reference to “high pressure” and “low pressure,” “high pressure” and “low pressure” may be relative to one another and may not connote certain pressure values (e.g., the pressure of the HP fluid in 130 is higher than thepressure of LP fluid in 120). The PX 410 may exchange pressure between the flows of geothermal fluid and may output flows of high pressure geothermal fluid and low pressure geothermal fluid. In some embodiments, the PX 410 may provide low pressure geothermal fluid via a low pressure outlet (e.g., LPout) and may provide high pressure geothermal fluid via a high pressure outlet (e.g., HPout). The high pressure geothermal fluid may be provided to the re-injection well 404 for re-injection into the hot aquifer 434.

[0070] After pressure is extracted (e.g., by the PX 410) from the high pressure geothermal fluid received from the production well 402, the low pressure geothermal fluid flows from the PX 410 (e.g., LPout) to a primary heat exchanger 426. In some embodiments, the primary heat exchanger 426 extracts energy associated with heat from the geothermal fluid and provides the extracted energy to a working fluid (e.g., CO2, water, hydrocarbons, refrigerant, etc.). The primary heat exchanger 426 may receive hot geothermal fluid and high pressure process fluid (e.g., high pressure gaseous CO2, high pressure liquid CO2 or high pressure supercritical CO2, etc.) and exchanges corresponding thermal energy between the two fluids. For example, in the primary heat exchanger 426, the process fluid may be heated by the geothermal fluid. Similarly, the geothermal fluid may be cooled by the process fluid. The cooled geothermal fluid may be pumped by a circulation pump 423 to LPin of the PX 410. Pressure of the cooled geothermal fluid may be increased in the PX 410 so that the cooled geothermal fluid can be re-injected into the hot aquifer 434 (e.g., via the re-injection well 404).

[0071] The heated working fluid (e.g., heated in the primary heat exchanger 426 by the hot geothermal fluid) may be provided to the turbine 428 to drive the turbine 428. In some embodiments, the turbine 428 is configured to be driven by a supercritical fluid, such as supercritical CO2. The working fluid may expand over the blades of the turbine 428 and cause the turbine blades and shaft to spin. The turbine 428 may convert energy from the working fluid into rotational kinetic energy. A generator 430 mechanically coupled with the turbine shaft may be caused to spin. The generator 430 may produce electricity 491. The generator 430 may convert the rotational kinetic energy into electrical energy. In some embodiments, the electricity 491 is used to produce hydrogen, such as by electrolyzer 494. Excess electricity 491 may be provided to the electrical grid (e.g., for powering off-site buildings, homes, processes, etc.). In some embodiments, the working fluid is output from the turbine 428 at a decreased temperature and at a decreased pressure.

[0072] The working fluid output from the turbine 428 may be provided to the recuperator 432 (e.g., heat exchanger, secondary heat exchanger, etc.). In some embodiments, therecuperator 432 is to extract any remaining thermal energy from the working fluid after expansion through turbine 428 and transfer the residual thermal energy to the fluid input to the primary heat exchanger (e.g., the fluid stream that is heated in the primary heat exchanger 426). Doing so may reduce the amount of heat added in the primary heat exchanger 426 for a given power output from the turbine 428, and may thus increase the efficiency of the system.

[0073] The gas cooler 418 may receive the working fluid output from the recuperator 432 and may further cool the working fluid. Heat not recovered from the working fluid in the recuperator 432 may be rejected to a corresponding environment (e.g., an ambient environment, etc.) via the gas cooler 418. In some embodiments, the gas cooler 418 acts as a thermal sink. In some embodiments, the density of the working fluid is increased in the gas cooler 418. The gas cooler 418 may use air or liquid cooling to cool the working fluid. In some embodiments, working fluid cooled in the gas cooler 418 remains in a supercritical state. In some embodiments, working fluid cooled in the gas cooler 418 may be in a subcritical liquid state. In some embodiments, the cooled working fluid is provided from the gas cooler 418 to the compressor 422. The compressor 422 may increase pressure of the working fluid. The compressor 422 may provide the working fluid to the recuperator 432 and / or to the primary heat exchanger 426 for receiving heat before the working fluid flows through the turbine 428.

[0074] The electricity 491 produced by the generator 430 may be provided to a rectifier 492. A rectifier may be an electrical device that converts alternating current (AC) into direct current (DC). AC is the type of electrical current delivered by power grids, while DC is used in most electronic devices, such as batteries and power supplies. A rectifier may use semiconductor devices like diodes to allow current to flow in only one direction, effectively "rectifying" the AC waveform. There are different types of rectifiers. For example, in a halfwave rectifier, only one half of the AC waveform is allowed to pass through, resulting in a pulsed DC output. In a full-wave rectifier, both halves of the AC waveform are used, but the current is flipped in the negative half to maintain a continuous DC output. A bridge rectifier may be a type of full-wave rectifier using four diodes arranged in a bridge configuration to convert AC into DC more efficiently. After rectification, the DC output may still have ripples (fluctuations in voltage), so additional filtering is often used to smooth the output for use in electronic circuits. In some embodiments, the rectifier 492 may be a half-wave rectifier, a full-wave rectifier, or a bridge rectifier. In some embodiments, the rectifier 492 may be a 6- pulse diode bridge rectifier, a 12-pulse diode bridge rectifier, or a thyrister-based rectifier. DC electricity may be provided by the rectifier 492 to electrolyzer 494. Responsive to beingenergized (e.g., with electricity), the electrolyzer 494 may produce gaseous hydrogen 496. The gaseous hydrogen 496 may be collected and prepared for storage and / or transport. For example, the gaseous hydrogen 496 may be compressed and / or liquefied for ease of storage and / or ease of transport.

[0075] FIG. 4B is a schematic diagram of a geothermal power generation sub-system 400B including a pressure exchanger (PX) 410, according to certain embodiments. In some embodiments, the PX 410 receives high pressure geothermal fluid from the hot aquifer 434 (e.g., via the production well 402) and low pressure working fluid (e.g., of the powergeneration cycle) from the gas cooler 418 (e.g., via the flow split valve 420). The low pressure working fluid may be in a supercritical state (e.g., having a temperature and pressure above the critical point of the working fluid). In the PX 410, pressure may be exchanged between the high pressure geothermal fluid and the low pressure working fluid to form low pressure geothermal fluid and high pressure working fluid. In some embodiments, low pressure geothermal fluid is provided from the PX 410 to the primary HX 426. Heat energy may be provided from the geothermal fluid to the working fluid in the primary HX 426, cooling the geothermal fluid to a low temperature . The low temperature and / or low pressure geothermal fluid may be provided back to the hot aquifer 434. In some embodiments, an injection pump 436 increases pressure of the geothermal fluid output from the primary HX 426 to re-inject the geothermal fluid into the hot aquifer 434.

[0076] In some embodiments, working fluid flowing from the gas cooler 418 is split into two flows by the flow split valve 420. In some embodiments, flow split valve 420 is a three- way valve to divert the flow of second fluid along two flow paths. Flow split valve 420 may be actuatable by a valve actuator. The actuator may actuate the flow split valve 420 based on instructions received from the controller 480. The instructions may be based on sensor data received by the controller 480 from one or more sensors of the system 400B. In some embodiments, the flow split valve 420 directs at least a portion of working fluid output from the gas cooler 418 toward LPin of the PX 410 to exchange pressure with the high pressure geothermal fluid within the PX 410. In some embodiments, the flow split valve 420 directs all of the working fluid output from the gas cooler 418 toward the LPin of the PX 410 to exchange pressure with the high pressure geothermal fluid within the PX 410 (e.g., bypassing the compressor 422 responsive to PX 410 providing enough pressure exchange). In some embodiments, the flow split valve 420 directs at least a portion of the working fluid output from the gas cooler 418 toward the compressor 422. In some embodiments, the flow split valve 420 directs all the working fluid output from the gas cooler 418 toward the compressor422 (e.g., bypassing the PX 410, such as during maintenance of the PX 410). In some embodiments, the compressor 422 increases pressure of the portion of the working fluid to a pressure similar (e.g., substantially similar) to that of the high pressure working fluid output from the PX 410. In some embodiments, compressed working fluid output from the compressor 422 is combined with high pressure working fluid output from the PX 410 in flow merge valve 424. Flow merge valve 424 may be an actuatable three-way valve actuated based on instructions received from the controller 480. In some embodiments, flow merge valve 424 actuates according to the actuation of flow split valve 420. In some embodiments, system 400B includes a simple pipe junction (e.g., a “T” junction) in place of flow merge valve 424 to merge the two flows.

[0077] In some embodiments, only a portion of the working fluid flows through the compressor 422. For example, approximately 70% of the working fluid output from the gas cooler 418 may flow through the PX 410 and approximately 30% of the working fluid may flow through the compressor 422. In another example, approximately 80% of the working fluid may flow through the PX 410 and approximately 20% of the working fluid may flow through the compressor 422. In another example, approximately 90% of the working fluid may flow through the PX 410 and approximately 10% of the working fluid may flow through the compressor 422. In another example, approximately 40% of the working fluid may flow through the PX 410 and approximately 60% of the working fluid may flow through the compressor 422. In another example, approximately 30% of the working fluid may flow through the PX 410 and approximately 70% of the working fluid may flow through the compressor 422. In another example, approximately 20% of the working fluid may flow through the PX 410 and approximately 80% of the working fluid may flow through the compressor 422. In another example, approximately 10% of the working fluid may flow through the PX 410 and approximately 90% of the working fluid may flow through the compressor 422. In some embodiments, flow through the compressor 422 is determined based on flowrate data and / or pressure data. In some embodiments, a combined flow output from the compressor and HPout of the PX 410 is to meet a threshold condition (e.g., a threshold flow rate). Depending upon mass flow rate from the HPout of the PX 410, more or less fluid may be caused to flow through the compressor 422. For example, if the mass flow rate from the HPout of the PX 410 is low (e.g., comparatively low), the flow split valve 420 may be actuated to send more working fluid through the compressor 422. In another example, if the mass flow rate from the HPout of the PX 410 is high (e.g., comparatively high,sufficiently high, etc.), the flow split valve 420 may be actuated to send less working fluid through the compressor 422.

[0078] In Som embodiments, the PX 410 extracts energy associated with pressure from the geothermal fluid and provides the energy to the working fluid. For example, the PX 410 may use pressure energy of the geothermal fluid to compress the working fluid of the power cycle ( e.g. CO2) without consuming external mechanical or electrical energy and thus reduces the energy consumed by the compressor 422. Doing so may increase the efficiency of the powergeneration system, which can lead to more hydrogen production per unit mass flow from the geothermal well

[0079] FIG. 4C is a schematic diagram of a geothermal power generation sub-system 400C including a pressure exchanger (PX) 410, according to certain embodiments. In some embodiments, the working fluid flows and drives the turbine 428 according to the Rankine cycle (e.g., the organic Rankine cycle). The working fluid may be water or may be an organic fluid such as a hydrocarbon ( e.g., isobutene, pentane, propane, etc.), a hydrofluorocarbon (HFC) (e.g., R134a, R245fa, etc.), or a hydrochlorofluorocarbon (HCFC), etc. An organic fluid may have a lower boiling point than water which may allow the organic fluid to evaporate (e.g., change phase from liquid to vapor) at a lower temperature than other fluids. Thus, an organic fluid may be an attractive option as a working fluid in the power-generation cycle when temperature of the fluid coming from the geothermal well is relatively low. By using an organic fluid, less heat may be consumed to evaporate the fluid (when compared to water), thus increasing the efficiency of the power-generation system.

[0080] The working fluid may receive heat (e.g., from the high temperature geothermal fluid) in the primary heat exchanger 426 and may at least partially evaporate. The working fluid may be provided to the turbine 428 to drive the turbine 428. In the turbine 428, the working fluid may expand and / or at least partially condense. The working fluid may flow (e.g., in the at least partially condensed state) to the regenerator 433. In some embodiments, the regenerator 433 is a heat exchanger to exchange corresponding thermal energy between the flow of working fluid from the turbine 428 and the flow of working fluid to the primary heat exchanger 426. In the regenerator 433, residual thermal energy may be extracted from the working fluid output from the turbine 428 and may be provided to the working fluid provided to the primary heat exchanger 426. The working fluid may flow from the regenerator 433 to the condenser 419. In some embodiments, heat from the working fluid is rejected to a corresponding environment (e.g., an ambient environment) by the condenser 419. In some embodiments, the working fluid condenses to a liquid in the condenser 419. Theliquid may be provided to a pump 423 which causes the liquid to flow to the regenerator 433 and / or to the primary heat exchanger 426.

[0081] FIG. 4D is a schematic diagram of a geothermal power generation sub-system 400D including a pressure exchanger (PX) 410, according to certain embodiments. In some embodiments, a heat exchanger 431 is provided to exchange corresponding thermal energy between the working fluid and coolant output from cooling coils 495 of the electrolyzer 494. The cooling coils 495 may cool the water (e.g., water and electrolyte mix) in the electrolyzer 494 so that the water is maintained at a substantially constant temperature. In some embodiments, the heat exchanger 431 provides residual heat from the working fluid (e.g., after the working fluid is expelled from the turbine 428) to the coolant. The coolant may carry the residual heat away from the heat exchanger 431. In some embodiments, the coolant receives heat from the electrolyzer 494 in the cooling coils 495. In some embodiments, the coolant carries the heat to a heat pump 499 (e.g., a heat pump sub-system, such as systems 500A-500D described herein below with respect to FIGS. 5A-5C). The coolant may flow along a circuit between the heat exchanger 431, the cooling coils 495, and / or a heat exchanger of the heat pump 499. A pump 425 may pump the coolant along the circuit.

[0082] FIG. 4E is a schematic diagram of a geothermal power generation sub-system 400E including a pressure exchanger (PX) 410, according to certain embodiments. In some embodiments, a booster pump 437 receives high pressure geothermal fluid output from the PX 410 (e.g., via HPout). The booster pump 437 may increase pressure of the high pressure geothermal fluid output from the PX 410 so that the geothermal fluid can be successfully reinjected into the hot aquifer 434. The booster pump 437 may be included in the system if the pressure of fluid at the re-injection well 404 is the same or higher than the pressure of fluid at the production well 402.

[0083] FIGS. 5A-C are schematic diagrams of heat pump sub-systems that each include a PX for use in a system for green hydrogen production, according to certain embodiments. Some of the features in one or more of FIGS. 5A-C may have similar properties, functions, and / or structures as those in one or more of FIGS. 1 A-D, FIGS. 2A-E, FIG. 3, and / or FIGS. 4A-D.

[0084] FIG. 5A is a schematic diagram of a heat pump sub-system 500A including a PX 510, according to certain embodiments. PX 510 may be a rotary pressure exchanger. In some embodiments, PX 510 is an isobaric or substantially isobaric pressure exchanger. In some embodiments, PX 510 is coupled to a motor 560. Rotation of the rotor (e.g., rotational velocity of the rotor) of PX 510 may be controlled by the motor 560.

[0085] In some embodiments, the PX 510 is configured to receive high pressure working fluid (e.g., HP fluid in 130 of FIGS. 1A-D) via a high pressure inlet (e.g., HPin) and low pressure working fluid (e.g., LP fluid in 120 of FIGS. 1 A-D) via a low pressure inlet (e.g., LPin). Although there is a reference to “high pressure” and “low pressure,” “high pressure” and “low pressure” may be relative to one another and may not connote certain pressure values (e.g., the pressure of the HP fluid in 130 is higher than the pressure of LP fluid in 120). PX 510 may exchange pressure between the high pressure working fluid and low pressure working fluid, effectively converting the received high pressure working fluid into low pressure working fluid and converting the received low pressure working fluid into high pressure working fluid. The PX 510 may output the converted low pressure working fluid via a low pressure outlet (e.g., LPout) and may output the converted high pressure working fluid via a high pressure outlet (e.g., HPout).

[0086] The system 500A may be configured to provide excess heat from the electrolyzer 594 (e.g., corresponding to electrolyzer 494 of FIGS. 4A-4D) to a process fluid (e.g., of process 596). The system 500A may include various components, including heat exchangers, to provide the heat from the electrolyzer 594 to the process fluid of process 596. The various components may flow a working fluid, such as a refrigerant (e.g., CO2, supercritical CO2, etc.), to transport heat from the electrolyzer 594 to the process fluid of process 596.

[0087] In some embodiments, system 500A includes a heat exchanger 576 to exchange corresponding thermal energy between the working fluid and the process fluid of process 596. The working fluid may be cooled in the heat exchanger 576 concurrent with the heating of the process fluid. In some embodiments, the temperature of the working fluid may be decreased in the heat exchanger 576, but the working fluid may not condense (e.g., the working fluid may not change phase from gas to liquid). In some embodiments, above the critical pressure of the working fluid, the thermodynamic distinction between liquid and gas phases disappear and there is only a single state of fluid, called the “supercritical state.”

[0088] In some embodiments, the process 596 may be a heating process or another heatconsuming process. For example, the process fluid of process 596 may be used to heat one or more buildings. In some embodiments, the process 596 is any process utilizing a heated process fluid. In some embodiments, the process fluid (e.g., of process 596) is water. The heat exchanger 576 may output heated process fluid (e.g., hot water, steam, etc.) to the process 596.

[0089] Low pressure working fluid from the PX 510 may be provided to a flash tank 513 (e.g., a receiver). In some embodiments, flash tank 513 is a receiver configured to receive aflow of working fluid from LPout of the PX 510. Flash tank 513 may form a chamber to collect the working fluid from LPout. Flash tank 513 may receive the working fluid in a two- phase state (e.g., liquid and gas). The working fluid (at a low pressure) may separate into gas and liquid inside flash tank 513. The liquid may settle in the bottom of the flash tank 513 while the gas may rise to the top of the flash tank 513. The liquid may flow from the flash tank 513 towards the heat exchanger 574 (e.g., via expansion valve 516). The chamber of flash tank 513 may be maintained at a set pressure (e.g., substantially maintained at a set pressure). The pressure may be set by a user (e.g., an operator, a technician, an engineer, etc.) and / or by a controller (e.g., controller 580). In some embodiments, the pressure of the flash tank 513 is controlled by one or more valves (e.g., expansion valve 516, flash gas valve 520, a pressure regulator valve, a safety valve, etc.). In some embodiments, the flash tank 513 includes at least one pressure sensor (e.g., a pressure transducer).

[0090] The expansion valve 516 may be disposed along a flow path between flash tank 513 and heat exchanger 574. Expansion valve 516 may be an adjustable valve (e.g., an electronic expansion valve, a thermostatic expansion valve, a ball valve, a gate valve, a poppet valve, etc.). Expansion valve 516 may be controllable by a user (e.g., a technician, an operator, an engineer, etc.) or by controller 580. In some embodiments, the expansion valve 516 is caused to actuate by controller 580 based on sensor data (e.g., pressure sensor data, flowrate sensor data, temperature sensor data, etc.). In some embodiments, expansion valve 516 is a thermal expansion valve. Expansion valve 516 may actuate (e.g., open and / or close) based on temperature data associated with the heat exchanger 574 (e.g., temperature data of the refrigeration fluid exiting the heat exchanger 574). In some embodiments, expansion valve 516 is controlled and actuated entirely based on electronic commands (e.g., from controller 580).

[0091] In some embodiments, a flash gas bypass flow path is formed. A flash gas valve 520 may be disposed along the flash gas bypass flow path. In some embodiments, the flash gas valve 520 regulates a flow of gas from a gas outlet of the flash tank 513. In some embodiments, the flow of gas from the flash tank 513 flows along the flash gas bypass flow path to bypass the heat exchanger 574. In some embodiments, the flash gas bypass flow path is between flash tank 513 and a location downstream of an outlet of the heat exchanger 574. The gas flowing along the flash gas bypass flow path may be combined with output of the heat exchanger 574. In some embodiments, flash gas valve 520 may be a bypass valve to regulate the flow of bypass gas (e.g., gas flowing along the gas bypass flow path). The flash gas valve 520 may cause gas collected in the flash tank 513 to expand (e.g., decrease inpressure) as the gas flows toward the compressor 522. The flash gas valve 520 may, in some embodiments, be an adjustable valve. In some embodiments, the flash gas valve 520 is caused to actuate by controller 580 based on sensor data.

[0092] In some embodiments, LP booster 514 (e.g., a low pressure booster) receives a flow of fluid from flash tank 513. In some examples, LP booster 514 receives a portion of the gas flowing along the flash gas bypass flow path between flash tank 513 and the flash gas valve 520, the LP booster 514 receiving a portion of gas diverted from the flash gas bypass flow path. In some embodiments, the LP booster 514 receives the fluid and increases pressure of the fluid to form the low pressure working fluid received by the PX 510 at LPin. In some embodiments, LP booster 514 is a compressor or a pump that operates over a low pressure differential to “boost” the pressure of the gas received from flash tank 513. In some embodiments, a compressor is configured to increase pressure of a fluid that is substantially gaseous, while a pump is configured to increase pressure of a fluid that is substantially liquid.

[0093] Thermal energy (e.g., heat) may be exchanged between the electrolyzer 594 and the heat pump by heat exchanger 574. In some embodiments, heat exchanger 574 exchanges corresponding thermal energy between coolant circulating through the cooling coils 595 (corresponding to cooling coils 495 of FIG. 4D) and the working fluid. The coolant may be pumped by pump 525 around a circuit formed between the heat exchanger 574 and the cooling coils 595.

[0094] In some embodiments, high pressure working fluid output from the PX 510 (e.g., via HPout) carries heat that can be provided to the process fluid of the process 596. The high pressure working fluid output from the PX 510 may be at a pressure that is nominally lower than the pressure of working fluid in the heat exchanger 576 (e.g., the pressure of fluid at HPout may be at least one bar lower than the pressure of fluid at HPin), so a separate heat exchanger may be used to provide heat from this fluid to the process fluid. In some embodiments, the high pressure working fluid may be provided from the PX 510 to a heat exchanger 578. The heat exchanger 578 may receive a portion of the process fluid via a valve 579. The remaining portion of the process fluid may flow to the heat exchanger 576 via the valve 579. In some embodiments, the actuation and / or position of the valve 579 may be controlled by controller 580. The heat exchanger 578 may exchange corresponding thermal energy between the working fluid (e.g., the high pressure working fluid output from the PX 510) and the process fluid (e.g., of process 596). The heated process fluid output from the heat exchanger 578 may join the heated process fluid output from the heat exchanger 576 for use in process 596. Each of the heat exchanger 576 and the heat exchanger 578 may receiverespective portions of the process fluid (of process 596) and provide heat from respective portions of the working fluid (of the heat pump sub-system) to the respective portions of the process fluid.

[0095] Working fluid output from the heat exchanger 574 and working fluid output from the heat exchanger 578 may be provided to a heat exchanger 572. In some embodiments, heat exchanger 572 exchanges corresponding thermal energy between the working fluid output from the heat exchanger 578 and the working fluid output from the heat exchanger 574. In some embodiments, a portion of the working fluid output from the heat exchanger 578 can bypass the heat exchanger 572 via a bypass valve 582.. In some embodiments, the bypass valve 582 is controllable by controller 580 (e.g., based on one or more sensor values, etc.) to regulate the flow of working fluid through the bypass valve 582.

[0096] The working fluid from the heat exchanger 578 may flow through the heat exchanger 572 (exchanging corresponding thermal energy in the heat exchanger 572 with working fluid output from the heat exchanger 574) to the flash tank 513. In some embodiments, this working fluid flows through a valve 584. The valve 584 may regulate the pressure of the working fluid. For example, the valve 584 may decrease pressure of the working fluid flowing through the valve 584 to substantially match the pressure of the fluid within the flash tank 513. In some embodiments, actuation of the valve 584 is controllable by the controller 580 (e.g., based on one or more sensor values, etc.). In some embodiments, working fluid output from valve 584 is joined with a portion of working fluid output from a valve 586. In some embodiments, valve 586 receives a portion of working fluid output from heat exchanger 576. The remaining portion of working fluid output from heat exchanger 576 may be provided to the PX 510 via HPin. High pressure working fluid entering the PX 510 via HPin may expand and / or decrease pressure (e.g., to form a low pressure fluid) in the PX 510 and may exit the PX 510 via LPout. The enthalpy extracted during expansion of the high pressure working fluid may be utilized by the PX 510 to compress the low pressure working fluid entering the PX 510 via LPin to a high pressure, forming high pressure working fluid. The high pressure working fluid may exit the PX 510 via HP out. The high pressure working fluid exiting the PX 510 (e.g., via HPout) may be in vapor state, supercritical state, or in two phase liquid-vapor mixture state. The compression of the low pressure working fluid to form the high pressure working fluid (e.g., fluid entering the PX via LPin and exiting the PX via HPout) may also increases the temperature of the working fluid. Therefore the high pressure fluid may exchange heat with the process fluid in heat exchanger 578. Because the compression of a portion of the working fluid is carried out by PX 510 using the energyextracted during expansion of high pressure fluid inside PX 510 (e.g., fluid entering the PX via HPin and exiting the PX via LPout), the energy consumed by the main compressor 522 may be reduced. Therefore, inclusion of the PX 510 may increase the efficiency of the heat pump system compared to conventional heat pump systems, such as systems that use a pressure valve to reduce the pressure of the working fluid. In some embodiments, the valve 586 may regulate the pressure of the working fluid and / or may control the amount of working fluid that flows into HPin of the PX 510. In some embodiments, actuation of the valve 586 is controllable by the controller 580 (e.g., based on one or more sensor values, etc.). In some embodiments, valve 586 decreases pressure of the working fluid flowing through the valve 586 to substantially match the pressure of the fluid within the flash tank 513.

[0097] The motor 560 may control the rotational speed of the rotor of PX 510. Control of the rotational speed of the rotor of PX 510 allows PX 510 to control the pressure in the heat exchanger 576. Under normal operation, valve 586 may remain closed. However, if there is more flow in the system than the volumetric capacity of PX 510, excess flow (e.g., excess flow that PX 510 cannot handle) is bypassed through valve 586. In some embodiments, the controller 580 causes the valve 586 to open gradually while maintaining the pressure in the heat exchanger 576 constant (e.g., at a given operating point). The controller 580 may determine to increase or decrease the pressure in the heat exchanger 576 to maintain a thermodynamically optimal level based on the temperature of the working fluid exiting the heat exchanger 576. In some embodiments, a proportional-integral-derivative (PID) control algorithm is used to determine the increase or decrease in pressure in the heat exchanger 576. The input to the PID control algorithm may be the real time measured values of temperature and / or pressure of the working fluid at the exit of the heat exchanger 576. The output of the PID control algorithm may be a signal that controls the motor 560 (e.g., controls the variable frequency drive (VFD) of the motor 560) and / or an actuator of the valve 586 (e.g., such as a stepper motor or servo motor, etc.).

[0098] The working fluid from the heat exchanger 574 may flow through the heat exchanger 572 (exchanging corresponding thermal energy in the heat exchanger 572 with working fluid output from the heat exchanger 578) to the compressor 522. In some embodiments, compressor 522 may increase the pressure of the working fluid output from the heat exchanger 574. The compressor 522 may provide the working fluid at an elevated pressure to the heat exchanger 576.

[0099] FIG. 5B is a schematic diagram of a heat pump sub-system 500B including a PX 510, according to certain embodiments. In some embodiments, a portion of the gas from theflash tank 513 flows through the flash gas valve 520 and is provided to a heat exchanger 573. As the gas flows through the flash gas valve 520, pressure of the gas decreases. As the pressure decreases, the temperature of the gas may also decrease. As the temperature of the gas decreases, a portion of the gas may condense into liquid. In some embodiments, the flow of high pressure working fluid from HP out of the PX 510 flows through the heat exchanger 578 (exchanging thermal energy with the process fluid of process 596 in the heat exchanger 578) and is provided to the heat exchanger 573. The heat exchanger 573 may exchange corresponding thermal energy between the high pressure working fluid and the fluid from the flash gas valve 520. In the heat exchanger 573, the high pressure working fluid may be cooled and the fluid from the flash gas valve 520 may be warmed. Cooling the high pressure working fluid exiting the heat exchanger 578 using heat exchanger 573 may increase the amount of liquid provided to the flash tank 513 via the valve 584. Warming the fluid from the flash gas valve 520 may vaporize liquid exiting the flash gas valve 520, thus decreasing the risk of liquid droplets entering the compressor 522. In some embodiments, substantially all the liquid in the fluid from the flash gas valve 520 evaporates in the heat exchanger 573 so that the fluid includes substantially all vapor. The vapor may be provided to the compressor 522 together with the output from the heat exchanger 574.

[0100] FIG. 5C is a schematic diagram of a heat pump sub-system 500C including a PX 510, according to certain embodiments. In some embodiments, the LP booster 514 can be eliminated from the heat pump sub-system. The low pressure working fluid provided to the PX 510 via LPin may be provided using the arrangement shown in FIG. 5C. In some embodiments, a portion of the working fluid output from the heat exchanger 576 is provided to a valve 587 and the remaining portion of working fluid may be provided to HPin of the PX 510 via the heat exchanger 581. In some embodiments, between approximately 10% and approximately 30 % of the working fluid output from the heat exchanger 576 is provided to the valve 587 and between approximately 70% and 90% of the working fluid output from the heat exchanger 576 is provided to HPin of the PX 510 via the heat exchanger 581. The valve 587 may decrease pressure of the provided portion of the working fluid. In some embodiments, valve 587 is controllable by controller 580. As pressure of the provided portion of the working fluid decreases in the valve 587, the temperature of the working fluid may decrease. Decreasing temperature of the working fluid may cause the working fluid to convert into a two-phase liquid-vapor mixture In some embodiments, corresponding thermal energy is exchanged between the portions of working fluid in the heat exchanger 581. In some embodiments, the flow of working fluid to HPin of PX 510 is cooled by the flow ofcolder working fluid from the valve 587. Liquid of the colder fluid exiting the valve 587 may vaporize because of this heat exchange. By cooling the flow of working fluid to HPin of PX 510, the proportion of liquid provided to the flash tank (via LPout) may be increased. Maximizing the amount of liquid provided to the flash tank 513 may maximize the amount of heat that can be absorbed by the working fluid (e.g., in heat exchanger 574), thus increasing the efficiency of the heat pump sub-system. In some embodiments, the portion of working fluid from the valve 587 is provided (via the heat exchanger 581) to LPin of PX 510 (e.g., for further compression in PX 510).

[0101] FIGS. 6A-D are schematic diagrams of systems having pressure exchangers for production of green hydrogen, electricity, and heat, according to certain embodiments. Some of the features in one or more of FIGS. 6A-D may have similar properties, functions, and / or structures as those in one or more of FIGS. 1A-D, FIGS. 2A-E, FIG. 3, FIGS. 4A-D, and / or FIGS. 5A-C. In some embodiments, the systems illustrated and described with respect to FIGS. 6A-D are combinations of sub-systems described herein above. For example, the systems illustrated and described with respect to FIGS. 6A-D may include a power generation sub-system (e.g., illustrated and described herein with respect to FIGS. 4A-D), an electrolyzer for green hydrogen production, and a heat pump sub-system (e.g., illustrated and described herein with respect to FIGS. 5A-C).

[0102] FIG. 6A is a schematic diagram of a system 600A, according to certain embodiments. In some embodiments, system 600A is substantially comprised of a combination of system 400A or 400E together with system 500A. System 400A may be a power generation sub-system and system 500A may be a heat pump sub-system. In some embodiments, system 600A includes a controller 680 to control the operation of the system (e.g., actuation of valves, control of motors, pumps, compressors, etc.). The controller 680 may include and / or perform the functions of each of controller 480 and / or controller 580 described herein above.

[0103] Each of the sub-systems (e.g., the power generation sub-system and the heat pump sub-system) may be associated with a common electrolyzer 694 (e.g., corresponding to electrolyzer 494 and electrolyzer 594). In some embodiments, the power generation subsystem generates electricity 491 for powering the electrolyzer 694 to produce hydrogen 496. In some embodiments, electricity 491 (generated by generator 430) is provided to the rectifier 492 which may convert the electricity 491 to DC current for the electrolyzer 694. In some embodiments, electricity 491 is used to power a motor 631 used to drive compressor 522. Excess electricity 491 may be provided to the electrical grid 696 (e.g., for powering off-sitebuildings, homes, processes, etc.). In some embodiments, the heat pump sub-system uses waste heat from the electrolyzer 694 to heat a process fluid of a process 596. In some embodiments, coolant flows through cooling coils 695 to cool the water (e.g., water mixed with electrolyte) in the electrolyzer 694. The coolant may become heated in the cooling coils 695. In some embodiments, the heated coolant flows from the cooling coils, carrying heat from the electrolyzer to the heat exchanger 574 to exchange corresponding thermal energy between the electrolyzer (e.g., via the coolant and cooling coils 695) and the system 500A.

[0104] FIG. 6B is a schematic diagram of a system 600B, according to certain embodiments. In some embodiments, system 600B is substantially comprised of a combination of system 400D together with system 500B. System 400D may be a power generation sub-system and system 500B may be a heat pump sub-system. In some embodiments, the hydrogen 496 (produced by the electrolyzer 694) is captured and provided to a compressor 698. The compressor 698 may be driven by a motor 633 that is powered using generated electricity 491. The compressor 698 may compress the hydrogen 496 to form compressed hydrogen 699. The compressed hydrogen 699 may be stored in one or more storage tanks. The compressed hydrogen 699 may be otherwise prepared for storage and / or transport.

[0105] Coolant may flow from the cooling coils 695 to the heat exchanger 574 and from the heat exchanger 574 to the cooling coils 695 and / or to the heat exchanger 431. In some embodiments, the heat exchanger 431 exchanged corresponding thermal energy between the coolant and the flow of working fluid output from the turbine 428. The coolant may carry absorbed heat (absorbed in the heat exchanger 431) from the system 400D to the heat exchanger 574. Thus, in some embodiments, the heat provided to the heat pump sub-system (e.g., system 500B) may include heat from the electrolyzer 694 and / or heat from the power generation sub-system (e.g., system 400D).

[0106] FIG. 6C is a schematic diagram of a system 600C, according to certain embodiments. In some embodiments, system 600C is substantially comprised of a combination of system 400C.1 (e.g., a modification of system 400C) together with system 500B. System 400C.1 may be a power generation sub-system and system 500B may be a heat pump sub-system. In some embodiments, system 400C.1 operates according to a Rankine power cycle (e.g., steam Rankine power cycle, an organic Rankine power cycle, etc.) as described with respect to FIG. 4C. In some embodiments, system 400C.1 uses water or an organic fluid such as a hydrocarbon, HFC or HCFC as the working fluid of te power cycle. In some embodiments, system 400C.1 includes heat exchanger 431 to provide heat from theworking fluid output from the turbine 428 to the coolant flowing between the heat exchanger 431, the heat exchanger 574, and / or the cooling coils 695.

[0107] FIG. 6D is a schematic diagram of a system 600D, according to certain embodiments. In some embodiments, system 600D is substantially comprised of a combination of system 400D together with system 500C. System 400D may be a power generation sub-system and system 500C may be a heat pump sub-system.

[0108] FIG. 7 is a flow diagram illustrating an example method 700 for an example system having pressure exchangers for production of green hydrogen, electricity, and heat (e.g., one of systems 600A-600D), according to certain embodiments. In some embodiments, method 700 can be implemented using a controller (e.g., controller 680) having hardware (e.g., circuitry, dedicated logic, programmable logic, microcode, processing device, etc.), software, software (such as instructions run on a processing device, a general purpose computer system, or a dedicated machine), firmware, microcode, or a combination thereof. In some embodiments, a non-transitory computer-readable storage medium stores instructions that when executed by a processing device, cause the processing device to perform one or more of the operations of method 700.

[0109] For simplicity of explanation, method 700 is depicted and described as a series of operations. However, operations in accordance with this disclosure can occur in various orders and / or concurrently and with other operations not presented and described herein. Furthermore, in some embodiments, not all illustrated operations are performed to implement method 700 in accordance with the disclosed subject matter. In addition, those skilled in the art will understand and appreciate that method 700 could alternatively be represented as a series of interrelated states via a state diagram or events.

[0110] At block 702, a first fluid is received, by a first PX, from a geothermal source. The first fluid may be a hot and / or high pressure geothermal fluid (e.g., water, brine, etc.). The geothermal fluid may have energy, such as energy associated with pressure and / or energy associated with heat. In some embodiments, the hot and / or high pressure geothermal fluid is received at a high pressure inlet (e.g., HPin) of the first PX. In some embodiments, the first PX additionally receives a second fluid. The second fluid may be a low pressure fluid, such as a low pressure and / or low temperature geothermal fluid, or a low pressure working fluid.

[0111] At block 704, pressure is exchanged, by the first PX, between the first fluid and the second fluid. In some embodiments, the first PX provides the pressure of the first fluid to the second fluid. For example, the first PX uses the high pressure of the first fluid to increase the pressure of the second fluid. Pressure from the first fluid may effectively be transferred to thesecond fluid, thus producing high pressure second fluid and low pressure first fluid. In some embodiments, the first PX extracts energy associated with pressure from the first fluid.

[0112] At block 706, first corresponding thermal energy is exchanged, by a first heat exchanger (HX), between the first fluid and a third fluid. In some embodiments, the first HX receives the low pressure first fluid from the first PX. The first fluid may be at high temperature when output from the first PX. In some embodiments, the first HX provides heat from the first fluid to the third fluid. The third fluid may be a working fluid, such as refrigerant, water, or a hydrocarbon, etc. as described herein above. In some embodiments, the first HX extracts energy associated with heat from the first fluid.

[0113] At block 708, corresponding energy of the third fluid is converted, by a turbine, into rotational kinetic energy. In some embodiments, the turbine receives the third fluid output from the first HX. The third fluid may expand as the third fluid flows through the turbine (e.g., flows across the blades of the turbine) and may drive the turbine, causing the turbine blades and shaft to rotate.

[0114] At block 710, the rotational kinetic energy is converted, by a generator, into electrical energy (e.g., electricity). In some embodiments, the generator is mechanically coupled with the turbine. Responsive to rotation of the turbine, the generator may generate electricity. In some embodiments, the electricity is AC or DC. The generated electricity may be provided to an electrolyzer. The electricity may be provided to the electrolyzer via a rectifier, in some embodiments.

[0115] At block 712, responsive to receiving the electrical energy (e.g., electricity), the electrolyzer produces gaseous hydrogen. In some embodiments, the electricity is provided to electrodes of the electrolyzer. The electrodes may be at least partially submerged in water (e.g., water mixed with an electrolyte) contained in the electrolyzer. The electrical energy may cause the water molecules to break apart into gaseous elemental hydrogen and elemental oxygen. The gaseous hydrogen may be captured and prepared for storage and / or transport (e.g., by compressing the hydrogen and providing the hydrogen into tanks, etc.). In some embodiments, the electrolyzer produces heat during the process of producing hydrogen. Coolant may flow through cooling coils of the electrolyzer to keep the water in the electrolyzer cool.

[0116] At block 714, second corresponding thermal energy is exchanged, by a second HX, between the electrolyzer and a heat pump sub-system. In some embodiments, the second HX is an evaporator of a heat pump (e.g., the heat pump sub-system). Heat from the electrolyzer may be provided to the second HX by the coolant flowing through the cooling coils of theelectrolyzer. In some embodiments, the coolant flows from the cooling coils to the second HX. Thermal energy may be exchanged between the coolant and a working fluid of the heat pump sub-system.

[0117] In some embodiments, the heat pump sub-system includes a second PX. At block 716, pressure is exchanged, by the second PX, between a fourth fluid and a fifth fluid. The fourth fluid and the fifth fluid may be individual streams of a working fluid in the heat pump sub-system. In some embodiments, the fourth fluid is a high pressure stream of working fluid and the fifth fluid is a low pressure stream of the working fluid. The second PX may use the high pressure of the fourth fluid to increase the pressure of the fifth fluid. Pressure from the fourth fluid may effectively be transferred to the fifth fluid, thus producing high pressure fifth fluid and low pressure fourth fluid. In some embodiments, the second HX is to receive at least a portion of the fourth fluid (e.g., low pressure fourth fluid) and provide the second corresponding thermal energy (e.g., from the coolant) to the fourth fluid.

[0118] At block 718, third corresponding thermal energy is exchanged, by a third HX, between the heat pump sub-system and a process fluid. In some embodiments, the heat pump sub-system upgrades the heat exchanged at the second HX by a heat pump cycle (e.g., including the second PX). The upgraded heat may be provided to the process fluid. In some embodiments, the process fluid is used in an otherwise unrelated process, such as a heating process, etc. The process fluid may be heated in the third HX (e.g., by the working fluid of the heat pump sub-system). In some embodiments, the process fluid may be used in a suitable process that utilizes a heated process fluid.

[0119] FIG. 8 is a block diagram illustrating a computer system 800, according to certain embodiments. In some embodiments, the computer system 800 is a client device. In some embodiments, the computer system 800 is a controller device (e.g., server, controller 180 of FIGS. 1A-D, controller 480 of FIGS. 4A-4D, controller 580 of FIGS. 5A-5C, controller 680 of FIGS. 6A-6D).

[0120] In some embodiments, computer system 800 is connected (e.g., via a network, such as a Local Area Network (LAN), an intranet, an extranet, or the Internet) to other computer systems. Computer system 800 operates in the capacity of a server or a 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 800 is provided by a personal computer (PC), a tablet PC, a Set-Top Box (STB), a Personal Digital Assistant (PDA), a cellular telephone, 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 actionsto be taken by that device. Further, the term "computer" shall include any collection of computers that individually or jointly execute a set (or multiple sets) of instructions to perform any one or more of the methods described herein.

[0121] In some embodiments, the computer system 800 includes a processing device 802, a volatile memory 804 (e.g., Random Access Memory (RAM)), a non-volatile memory 806 (e.g., Read-Only Memory (ROM) or Electrically-Erasable Programmable ROM (EEPROM)), and / or a data storage device 816, which communicates with each other via a bus 808.

[0122] In some embodiments, processing device 802 is provided by one or more processors such as a general purpose processor (such as, for example, a Complex Instruction Set Computing (CISC) microprocessor, a Reduced Instruction Set Computing (RISC) microprocessor, a Very Long Instruction Word (VLIW) microprocessor, a microprocessor implementing other types of instruction sets, or a microprocessor implementing a combination of types of instruction sets) or a specialized processor (such as, for example, an Application Specific Integrated Circuit (ASIC), a Field Programmable Gate Array (FPGA), a Digital Signal Processor (DSP), or a network processor). In some embodiments, processing device 802 is provided by one or more of a single processor, multiple processors, a single processor having multiple processing cores, and / or the like.

[0123] In some embodiments, computer system 800 further includes a network interface device 822 (e.g., coupled to network 874). In some embodiments, the computer system 800 includes one or more input / output (I / O) devices. In some embodiments, computer system 800 also includes a video display unit 810 (e.g., a liquid crystal display (LCD)), an alphanumeric input device 812 (e.g., a keyboard), a cursor control device 814 (e.g., a mouse), and / or a signal generation device 820.

[0124] In some implementations, data storage device 818 (e.g., disk drive storage, fixed and / or removable storage devices, fixed disk drive, removable memory card, optical storage, network attached storage (NAS), and / or storage area-network (SAN)) includes a non- transitory computer-readable storage medium 824 on which stores instructions 826 encoding any one or more of the methods or functions described herein, and for implementing methods described herein.

[0125] In some embodiments, instructions 826 also reside, completely or partially, within volatile memory 804 and / or within processing device 802 during execution thereof by computer system 800, hence, volatile memory 804 and processing device 802 also constitute machine-readable storage media, in some embodiments.

[0126] While computer-readable storage medium 824 is shown in the illustrative examples as a single medium, the term "computer-readable storage medium" shall include a single medium or multiple media (e.g., a centralized or distributed database, and / or associated caches and servers) that store the one or more sets of executable instructions. The term "computer-readable storage medium" shall also include any tangible medium that is capable of storing or encoding a set of instructions for execution by a computer that cause the computer to perform any one or more of the methods described herein. The term "computer- readable storage medium" shall include, but not be limited to, solid-state memories, optical media, and magnetic media.

[0127] The methods, components, and features described herein may be implemented by discrete hardware components or may be integrated in the functionality of other hardware components such as ASICS, FPGAs, DSPs or similar devices. In addition, the methods, components, and features may be implemented by firmware modules or functional circuitry within hardware devices. Further, the methods, components, and features may be implemented in any combination of hardware devices and computer program components, or in computer programs.

[0128] Unless specifically stated otherwise, terms such as “actuating,” “adjusting,” “causing,” “controlling,” “determining,” “identifying,” “providing,” “receiving,” “flowing,” “receiving,” “exchanging,” “converting,” “producing,” or the like, refer to actions and processes performed or implemented by computer systems that manipulates and transforms data represented as physical (electronic) quantities within the computer system registers and memories into other data similarly represented as physical quantities within the computer system memories or registers or other such information storage, transmission or display devices. Also, the terms "first," "second," "third," "fourth," etc. as used herein are meant as labels to distinguish among different elements and may not have an ordinal meaning according to their numerical designation.

[0129] Examples described herein also relate to an apparatus for performing the methods described herein. This apparatus may be specially constructed for performing the methods described herein, or it may include a general purpose computer system selectively programmed by a computer program stored in the computer system. Such a computer program may be stored in a computer-readable tangible storage medium.

[0130] 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 morespecialized apparatus to perform methods described herein and / or each of their individual functions, routines, subroutines, or operations. Examples of the structure for a variety of these systems are set forth in the description above.

[0131] The preceding description sets forth numerous specific details, such as examples of specific systems, components, methods, and so forth, in order to provide a good understanding of several embodiments of the present disclosure. It will be apparent to one skilled in the art, however, that at least some embodiments of the present disclosure may be practiced without these specific details. In other instances, well-known components or methods are not described in detail or are presented in simple block diagram format in order to avoid unnecessarily obscuring the present disclosure. Thus, the specific details set forth are merely exemplary. Particular implementations may vary from these exemplary details and still be contemplated to be within the scope of the present disclosure.

[0132] Reference throughout this specification to “one embodiment” or “an embodiment” means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment. Thus, the appearances of the phrase “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 term “or” is intended to mean an inclusive “or” rather than an exclusive “or.” When the term “about,” “substantially,” or “approximately” is used herein, this is intended to mean that the nominal value presented is precise within ±10%. Also, the terms "first," "second," "third," "fourth," etc. as used herein are meant as labels to distinguish among different elements and can not necessarily have an ordinal meaning according to their numerical designation.

[0133] The terms “over,” “under,” “between,” “disposed on,” and “on” as used herein refer to a relative position of one material layer or component with respect to other layers or components. For example, one layer disposed on, over, or under another layer may be directly in contact with the other layer or may have one or more intervening layers.Moreover, one layer disposed between two layers may be directly in contact with the two layers or may have one or more intervening layers. Similarly, unless explicitly stated otherwise, one feature disposed between two features may be in direct contact with the adjacent features or may have one or more intervening layers.

[0134] Although the operations of the methods herein are shown and described in a particular order, the order of the operations of each method may be altered so that certain operations may be performed in an inverse order or so that certain operation may be performed, at least in part, concurrently with other operations. In another embodiment,instructions or sub-operations of distinct operations may be in an intermittent and / or alternating manner. In one embodiment, multiple metal bonding operations are performed as a single step.

[0135] 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 skill in the art upon reading and understanding the above description. The scope of the 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

CLAIMSWhat is claimed is:

1. A system, comprising: a power generation sub-system configured to generate electrical energy, the power generation sub-system comprising: a first pressure exchanger (PX) configured to exchange pressure between a first fluid received from a geothermal source and a second fluid; a first heat exchanger configured to exchange first corresponding thermal energy between the first fluid received from the geothermal source and a third fluid; a turbine configured to receive the third fluid and convert corresponding energy of the third fluid into rotational kinetic energy; and a generator mechanically coupled with the turbine and configured to convert the rotational kinetic energy into the electrical energy; an electrolyzer configured to produce gaseous hydrogen responsive to receiving the electrical energy; and a heat pump sub-system configured to heat a process fluid, the heat pump sub-system comprising: a second heat exchanger configured to exchange second corresponding thermal energy between the electrolyzer and the heat pump sub-system; a third heat exchanger configured to exchange third corresponding thermal energy between the heat pump sub-system and at least a first portion of the process fluid; and a second PX configured to exchange pressure between a fourth fluid and a fifth fluid, wherein the second heat exchanger is to receive at least a portion of the fourth fluid and provide the second corresponding thermal energy to the fourth fluid.

2. The system of claim 1, further comprising: a fourth heat exchanger configured to receive fluid output from the turbine and exchange fourth corresponding thermal energy between the fluid output from the turbine and the third fluid input to the first heat exchanger to heat the third fluid input to the first heat exchanger.

3. The system of claim 2, further comprising: a fifth heat exchanger configured to receive fluid output from the fourth heat exchanger, and further configured to exchange fifth corresponding thermal energy between the fluid output from the fourth heat exchanger and a corresponding environment.

4. The system of claim 1, further comprising: a pump configured to receive the first fluid output from the first heat exchanger, increase pressure of the first fluid to form the second fluid, and provide the second fluid to the first PX.

5. The system of claim 1, wherein the first PX is configured to provide the second fluid to the geothermal source.

6. The system of claim 1, wherein the second fluid is geothermal fluid provided by the first PX to the geothermal source or wherein the second fluid is third fluid output from the turbine.

7. The system of claim 1, wherein the fourth fluid and the fifth fluid comprises at least one of carbon dioxide (CO2), R-134a, R-404a, R-410a, R-454b, ammonia, a hydrocarbon, or a hydrofluorocarbon, and wherein the third fluid comprises water, CO2, a hydrofluorocarbon, or a hydrocarbon.

8. The system of claim 1, wherein the second heat exchanger is configured to receive heated coolant from cooling coils associated with the electrolyzer and to exchange the second corresponding thermal energy between the heated coolant and the at least the portion of the fourth fluid.

9. The system of claim 1, further comprising: a receiver configured to receive at least the fourth fluid output from the second PX, wherein the receiver forms a chamber configured to separate the fourth fluid into a first gas and a first liquid; and an expansion valve configured to receive the first liquid from the receiver and decrease pressure of the first liquid to form the fourth fluid provided to the second heat exchanger.

10. The system of claim 9, further comprising: a bypass valve configured to receive at least a portion of the first gas from the receiver; and a sixth heat exchanger configured to receive at least the portion of the first gas from the bypass valve and the fifth fluid output from the second PX, wherein the sixth heat exchanger is configured to exchange sixth corresponding thermal energy between the at least the portion of the first gas the fifth fluid.

11. The system of claim 1, further comprising: a seventh heat exchanger configured to receive the fifth fluid output from the second PX, wherein the seventh heat exchanger is configured to exchange seventh corresponding thermal energy between the fifth fluid and a second portion of the process fluid; a valve configured to receive the fifth fluid output from the seventh heat exchanger and reduce pressure of the fifth fluid.

12. The system of claim 11, further comprising: an eighth heat exchanger configured to receive the fifth fluid output from the seventh heat exchanger and the at least the portion of the fourth fluid output from the second heat exchanger, the eighth heat exchanger further configured to exchange eighth corresponding thermal energy between the fifth fluid and the at least the portion of the fourth fluid; and a second bypass valve configured to allow a portion of the fifth fluid to bypass the the eighth heat exchanger.

13. The system of claim 1, further comprising: a ninth heat exchanger configured to receive the third fluid output from the turbine and a sixth fluid, wherein the ninth heat exchanger is configured to exchange ninth corresponding thermal energy between the third fluid and the sixth fluid, and wherein the ninth heat exchanger is configured to provide at least a portion of the sixth fluid to the second heat exchanger.

14. A method, comprising: receiving, by a first pressure exchanger (PX) a first fluid from a geothermal source; exchanging pressure, by the first PX, between the first fluid and a second fluid;exchanging first corresponding thermal energy, by a first heat exchanger, between the first fluid and a third fluid; converting corresponding energy of the third fluid, by a turbine, into rotational kinetic energy; converting, by a generator, the rotational kinetic energy into electrical energy; responsive to receiving the electrical energy, producing, by an electrolyzer, gaseous hydrogen; exchanging second corresponding thermal energy, by a second heat exchanger, between the electrolyzer and a heat pump sub -system; exchanging pressure, by a second PX, between a fourth fluid and a fifth fluid, wherein the second heat exchanger is to receive at least a portion of the fourth fluid and provide the second corresponding thermal energy to the at least the portion of the fourth fluid; and exchanging third corresponding thermal energy, by a third heat exchanger, between the heat pump sub-system and a first portion of a process fluid.

15. The method of claim 14, further comprising: exchanging fourth corresponding thermal energy, by a fourth heat exchanger, between the third fluid output from the turbine and a sixth fluid; and providing, by the fourth heat exchanger, at least a portion of the sixth fluid to the second heat exchanger.

16. The method of claim 14, further comprising: receiving, by the second heat exchanger, heated coolant from cooling coils associated with the electrolyzer, wherein the second heat exchanger is to exchange the second corresponding thermal energy between the heated coolant and the at least the portion of the fourth fluid.

17. The method of claim 14, further comprising: exchanging fifth corresponding thermal energy, by a fifth heat exchanger, between the fifth fluid output from the second PX and a second portion of the process fluid; and exchanging sixth corresponding thermal energy, by a sixth heat exchanger, between the fifth fluid output from the fifth heat exchanger and the at least a portion of the fourth fluid output from the second heat exchanger.

18. A system, comprising: a power generation sub-system configured to generate electrical energy responsive to receiving a first fluid from a geothermal source, wherein the power generation sub-system comprises a first pressure exchanger (PX) configured to extract first energy associated with pressure from the first fluid, and wherein the power generation sub-system further comprises a first heat exchanger configured to extract second energy associated with heat from the first fluid; an electrolyzer configured to produce gaseous hydrogen responsive to being energized using the electrical energy; and a heat pump sub-system configured to heat a process fluid using excess thermal energy from the electrolyzer, wherein the heat pump sub-system comprises a second PX configured to exchange pressure between a second fluid and a third fluid, wherein the heat pump sub-system further comprises a second heat exchanger configured to receive at least a portion of the second fluid and provide the excess thermal energy from the electrolyzer to the at least the portion of the second fluid.

19. The system of claim 18, wherein the power generation sub-system comprises a turbine mechanically coupled with a generator to generate the electrical energy, and wherein the power generation sub-system uses a supercritical carbon dioxide (CO2) power cycle or an organic Rankine power cycle using the first energy and the second energy to power the turbine.

20. The system of claim 18, wherein the heat pump sub-system further comprises one or more third heat exchangers configured to receive respective portions of the process fluid and provide thermal energy from the heat pump sub-system to the respective portions of the process fluid.

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