Method, system and apparatus for extracting thermal energy from geothermal saline fluids

Abstract

The present disclosure relates to techniques for extracting thermal energy from geothermal brine fluid. The brine fluid may be extracted from a geothermal production well and delivered to a heat exchanger. The heat exchanger may receive the brine fluid and transfer thermal energy from the brine fluid to molten salt. The molten salt may be pumped to a molten salt storage tank, which may function as energy storage. The brine fluid may be returned to a geothermal source via a production well. The brine fluid may remain separate from the molten salt in a closed-loop system from when it is extracted until it is returned to the geothermal production well. [Selected Figure] Figure 1

Description

[Technical field]

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS This application claims the benefit of U.S. Provisional Patent No. 62 / 687,385, filed June 20, 2018, which is incorporated by reference in its entirety.

[0002] Technical Field FIELD OF THE DISCLOSURE This disclosure relates to geothermal energy extraction, and more particularly, to extracting thermal energy from geothermal brine fluids. [Background technology]

[0003] Thermal energy lies dormant beneath the Earth's surface in the form of geothermal energy. The Earth's core is believed to be over 5,000°C and contains enough heat, stored since the Earth's formation and generated by ongoing radioactive decay, to provide a vast amount of energy.

[0004] However, many attempts to harness geothermal energy in general encounter many problems accessing it because the Earth's surface is significantly cooler than the Earth's interior. The average geothermal gradient is about 25°C for every kilometer of depth below the Earth's surface. Thus, the temperature at the bottom of a 5 km deep well can be roughly 125°C or more.

[0005] In many cases, various entities are able to drill into the earth at similar depths (e.g., up to 12 km deep) in search of resources (e.g., oil). However, operating wells at such depths can be very resource intensive.

[0006] Additionally, near geological fault zones, ruptures in the Earth's crust can bring magma very close to the Earth's surface. This can result in geothermal features such as volcanoes, natural hot springs, and geysers. As an example, in the seismically active Long Valley Caldera in California, magma with temperatures in excess of 700 °C is thought to be located just 6 km below the Earth's surface. Alternatively, wells less than 1 km deep in geothermal fields can achieve temperatures in excess of 100 °C, if lower temperatures are available. Wells only 1 km deep are often much less resource intensive than operating deeper wells.

[0007] In some locations, previous drilling activity may mean that drilling is not necessary. As an example, areas where oil exploration has taken place in the past may still have many underground wells remaining, and some of these wells may reach deep enough below the Earth's surface to capture geothermal heat. These wells may only need to be provided with surface infrastructure to be able to capture this heat source. Summary of the Invention

[0008] The disclosed techniques include transferring thermal energy from a closed-loop brine fluid system to molten salt. The closed-loop brine fluid system may include extraction and injection wells extending deep into the earth. The depths of the extraction and injection wells may be a function of the geothermal temperature gradient. The brine fluid extracted via the extraction wells may be sent to a heat exchanger configured to transfer thermal energy from the brine fluid to the molten salt system. Because a closed-loop system is used, all or substantially all of the brine fluid is returned to the geothermal source via the injection wells after extracting the thermal energy. The molten salt can store thermal energy for long periods of time. The molten salt may also be used to transport the stored thermal energy to another location. For example, the molten salt may be used to transfer the stored thermal energy to a remote electric generating unit (EGU). [Brief description of the drawings]

[0009] These and other objects, features and characteristics of the present disclosure will become more apparent to those skilled in the art from a consideration of the following detailed description taken in conjunction with the accompanying claims and drawings, all of which are incorporated herein by reference.

[0010] [Figure 1] FIG. 1 illustrates a block diagram of a system for extracting thermal energy from geothermal brine fluid, according to various embodiments.

[0011] [Diagram 2] FIG. 2 illustrates a block diagram of a system for extracting heat from a saltwater fluid to molten salt, according to various embodiments.

[0012] [Diagram 3] FIG. 3 shows a block diagram of a molten salt geothermal system with lithium extraction according to various embodiments.

[0013] [Figure 4] FIG. 4 illustrates a block diagram of an energy harvesting system, according to various embodiments.

[0014] [Diagram 5] FIG. 5 illustrates an isometric view of a saltwater fluid to molten salt geothermal thermal energy extraction system according to various embodiments.

[0015] [Figure 6] FIG. 6 is an isometric view of an industrial park substantially powered by geothermal energy, according to various embodiments.

[0016] [Figure 7] FIG. 7 illustrates a block diagram of a system for extracting energy from geothermal brine fluid, according to various embodiments.

[0017] [Figure 8]FIG. 8 illustrates a block diagram of a geothermal heat extraction management system according to various embodiments.

[0018] [Figure 9] FIG. 9 is a block diagram illustrating a method for collecting thermal energy from a saltwater fluid, according to various embodiments. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0019] In many cases, geothermal technologies may experience scaling due to flash steaming of the brine fluids and may not be able to reinject substantially all of the brine fluids back into the geothermal well after the thermal energy has been extracted. Conventional geothermal technologies may not be able to store the energy for later use and may not be able to transport the heat to a secondary location for thermal processing or power generation. Additionally, these geothermal technologies may have a high potential for toxic vapor emissions, especially during plant shutdowns.

[0020] The disclosed embodiments may solve problems inherent in many geothermal processes involving the extraction of thermal energy from geothermal brine fluid. In one embodiment, thermal energy is transferred from the brine fluid to molten salt via a heat exchanger. In one embodiment, thermal energy is transferred directly from the brine fluid to rock formations. Energy extracted from the geothermal fluid may be used to heat electrodes in a storage tank of molten silicon or molten glass. Thermal energy may be transferred from the molten salt to thermal oil or hot water. In one embodiment, one or more materials (e.g., lithium) may be extracted from the brine fluid.

[0021] The brine fluid is not flashed as in other technologies, so the installation is not limited by scaling. Additionally, a closed loop system may be used such that all or substantially all of the brine fluid is returned to the geothermal well after the thermal energy is extracted. For example, the thermal energy may be transferred directly to the molten salt, which may store thermal energy for long periods of time. The molten salt may also be used to transport the stored thermal energy to another location. Additionally, the molten salt may be used to transfer heat to other materials, such as thermal fluids. For example, the molten salt may be used to transfer the stored thermal energy to a remote electric generating unit (EGU).

[0022] Figure 1 illustrates a block diagram of a system for extracting thermal energy from geothermal brine fluid, according to various embodiments. The embodiment illustrated in Figure 1 employs a molten salt geothermal energy collection system to extract thermal energy from geothermal brine fluid.

[0023] Geothermal resources may include brine fluids having a temperature range of 175°C to 800°C. The temperature of the brine fluid in a geothermal resource may be a function of depth. Brine fluid in the range of 175°C to 800°C is extracted through a production well 1, directed through a rate control valve and pump, and pumped into a hot brine fluid inlet pipe to a brine fluid to molten salt heat exchanger 2 (a heat exchanger that transfers heat from the brine fluid to the molten salt).

[0024] The speed control valve, pump and associated components may be made of oxidation and corrosion resistant materials such as, for example, stainless steel, Inconel alloy, or dual piping. In one embodiment, the oxidation and corrosion resistant materials may be made primarily of non-ferrous metals such as chromium and / or nickel. Additionally, the speed control valve, pump and associated components may be lined with corrosion resistant chemicals or materials such as, for example, high density polyethylene (HDPE).

[0025] The speed control valves and pumps may control the pressure between the production well 1, the saltwater fluid to molten salt heat exchanger 10, and the reinjection well 3. For example, the speed control valves and pumps may be used to maintain a constant pressure. To maintain a constant pressure, the valves and pumps may vary the flow rate of the saltwater fluid based on a series of sensors. These sensors may check the flow rate of the saltwater fluid at checkpoints in the system. In one embodiment, sensors may be installed at the base of the production well, before and after the valves and pumps, inside the heat exchanger, and at the base of the reinjection well. If any of these sensors detect a pressure (e.g., in psi) lower or higher than the pressure in the geothermal source, the sensor may instruct the valves and pumps to adjust the pressure. For example, a sensor at the base of the production well may indicate 900 psi. However, a sensor at the base of the reinjection well may indicate 500 psi. A sensor at the bottom of the reinjection well may indicate the valves and pumps to speed up the flow rate to match the 900 psi. In some embodiments, all of the valves and pumps installed in the system may operate simultaneously. In other embodiments, some valves and pumps may operate independently of others.

[0026] The molten salt may include a eutectic mixture of different salts (e.g., sodium nitrate, potassium nitrate, and / or calcium nitrate). The molten salt may travel from the saltwater fluid to molten salt heat exchanger 10 through a first line 5 to a hot molten salt storage tank 7.

[0027] The cold molten salt from the cold molten salt storage tank 8 may be transferred to the saltwater fluid to molten salt heat exchanger 10 via the second piping 6. The cold molten salt may be heated by the saltwater fluid in the saltwater fluid to molten salt heat exchanger 10 and the heated molten salt may be pumped to the hot molten salt storage tank 7 via the first piping 5. The hot molten salt in the hot molten salt storage tank 7 may be distributed throughout the facility (e.g., an industrial park) and / or sent to an energy generation unit. In one embodiment, a graphite block with multiple grooves may be used to absorb heat from the saltwater fluid and store the thermal energy.

[0028] In one embodiment, nanoparticles can be added to the molten salt at any point in the closed loop system. The heat storage capacity of the mixture of molten salt and nanoparticles can be up to 30% higher than the molten salt alone. Nanoparticles include, for example, copper-studded graphite or graphene. For example, graphene can be added to the molten salt in a hot molten salt tank or in a heat exchanger from the saltwater fluid to the molten salt.

[0029] The saltwater fluid to molten salt heat exchanger 10 may be used to transfer heat from the extracted saltwater fluid to the molten salt. The saltwater fluid and the molten salt may be separated, for example, by a thermally conductive wall. The thermally conductive wall may be thermally conductive at high pressure. The thermally conductive wall may include, for example, copper, silver, diamond (e.g., pure diamond, impure diamond, and / or isotopically enriched diamond), gold, aluminum, carbon fiber, stainless steel titanium alloy, or any combination thereof. In one embodiment, the thermally conductive wall may include a layer of isotopically enriched diamond adjacent to the saltwater fluid chamber and a layer of copper adjacent to the molten salt chamber. The isotopically enriched diamond layer may be used adjacent to the saltwater fluid chamber to reduce corrosion while maintaining high thermal conductivity.

[0030] In one embodiment, the saltwater fluid to molten salt heat exchanger 10 includes a temperature sensor. The temperature sensor may sense the temperature of both the saltwater fluid and the molten salt. When the temperature of the saltwater fluid, the molten salt, or both reaches a preset value, the system may then move the heated molten salt to the hot molten salt tank. In addition, the system may move the cold saltwater fluid to the reinjection well and pump the hot saltwater fluid to the heat exchanger. For example, the threshold for the molten salt to move to the hot molten salt tank may be 300° C. When the temperature sensor detects that the molten salt has reached 300° C., the temperature sensor may provide instructions to move the hot molten salt to the hot molten salt tank 7 and to allow the cold molten salt into the saltwater fluid to molten salt heat exchanger 10.

[0031] After heat is extracted from the brine fluid entering the brine fluid to molten salt heat exchanger 10, the brine fluid may be recycled back into the resource. At this point, the rising brine fluid has transferred heat to the molten salt or rock and been recycled back into the geothermal resource. In one embodiment, cold molten salt from the cold molten salt storage tank 8 enters the heat exchanger 10 and is heated before being pumped to the hot molten salt storage tank 7. In one embodiment, the heated molten salt is used to heat a thermal fluid, such as thermal oil and water. The molten salt may then be passing through a molten salt to distilled water heat exchanger.

[0032] The hot molten salt may enter a molten salt-to-distilled water heat exchanger 20 via a third line 9. The steam produced from the molten salt-to-distilled water heat exchanger 20 may then be sent to a steam turbine 50 or generator set (GenSet) via a fourth line 21 to generate electricity.

[0033] The steam may pass through a condenser / cooling tower 23 to be converted to water, thereby repeating the molten salt to distilled water loop. The steam may be sent through a fifth line 17 to a molten salt to thermal oil heat exchanger 30, through a sixth line 18 to a molten salt to hot water heat exchanger 40, and then sent back to the cold molten salt storage tank 8 (where it waits to be reheated by the hot brine fluid).

[0034] The steam may be sent via a seventh line 31 to a thermal oil storage tank 32 and via an eighth line 33 to a cooled thermal oil storage tank 34. The cooled thermal oil may be sent via a ninth line 35 to a cool to cold thermal oil storage tank 36.

[0035] From the molten salt to hot water heat exchanger 40, the hot water may be sent to a hot water storage tank 42 via a tenth line 41. The hot water may be sent from the hot water storage tank 42 to a hot water system 44 via an eleventh line 43. The cool water may be sent to a cold water storage tank 46 via a twelfth line 45. The cool water may be sent back to the molten salt to hot water heat exchanger 40 via a thirteenth line 47.

[0036] Steam turbine 50 may rotate rotor 51, which enables generator 52 to provide electrical energy. A transformer 53 then converts this electrical energy to facilitate transmission of three-phase electricity 55 to the power grid.

[0037] In one embodiment, the energy harvesting system may include a molten silicon heat exchanger 62. Electrodes (e.g., using electricity generated at a geothermal power plant) may be heated in a storage tank of molten silicon to 60-2000°C. The molten silicon may be used in a heat exchanger 62 with molten salt to raise the temperature of the molten salt to a higher operating temperature (e.g., such as 1000°C). In one embodiment, molten glass may be used in the heat sink. The molten glass may be heated by electrodes to 1200°C. The molten salt may be pumped back to the hot molten salt storage chamber 7 via return lines 64, 65.

[0038] FIG. 2 shows a block diagram of a saltwater fluid to molten salt heat extraction system according to various embodiments. The embodiment shown in FIG. 2 may include a saltwater fluid to molten salt heat extraction system with different thermal fluid loops, such as, for example, thermal oil and hot water loops. By using different thermal fluids, the system can be used in a wide range of applications and can be made more efficient. Closed-loop thermal oil heat exchangers and closed-loop hot water heat exchangers can be incorporated into the system to cater for thermal processes utilizing different temperature ranges. For example, thermal oil can be circulated through a thermal oven and in a molten salt to water heat exchanger. By circulating the thermal oil, the amount of steam generated can be maximized.

[0039] Hot brine fluid may be collected from a production well 1 and transferred via a first pipe 2 to a brine fluid-to-molten salt heat exchanger 10. The hot molten salt from the brine fluid-to-molten salt heat exchanger 10 may be transferred via a second pipe 5 to a hot molten salt storage chamber 7. The cold molten salt may be transferred between the cold molten salt storage chamber 8 and the brine fluid-to-molten salt heat exchanger 10 via a third pipe 6.

[0040] The molten salt may be transferred to a molten salt to hot water for steam heat exchanger 20 via a fourth line 9. The molten salt to hot water for steam heat exchanger 20 may power a steam turbine 50 via a fifth line 21. The steam turbine 50 may power a rotor 51, a generator 52, a transformer 53, and three-phase power to a power grid 54.

[0041] The cool steam may travel from the steam turbine 50 via a sixth line 22 to a condenser or cooling tower 23 and back to the molten salt to hot water for steam heat exchanger 20 via a seventh line 24. The molten salt may travel from the molten salt to steam heat exchanger 20 to the molten salt to thermal oil heat exchanger 30 via an eighth line 25.

[0042] Thermal oil may travel between the molten salt to thermal oil heat exchanger 30 and the thermal oil storage tank 32 via a ninth line 31. Thermal oil may travel between the thermal oil storage tank 32 and the thermal oil system 34 via a tenth line 33. Cool thermal oil may travel from the thermal oil system 34 to the cool thermal oil storage tank 36 via an eleventh line 35. Cool thermal oil may travel from the cool thermal oil storage tank 36 back to the molten salt to thermal oil heat exchanger 30 via a twelfth line 37.

[0043] Molten salt may travel between the molten salt-to-thermal oil heat exchanger 30 and the molten salt-to-hot water heat exchanger 40 via a thirteenth line 38. Hot water may travel between the molten salt-to-hot water heat exchanger 40 and the hot water storage tank 42 via a fourteenth line 41. Hot water may travel between the hot water storage tank 42 and the hot water system 44 via a fifteenth line 43. Water may travel between the hot water system 44 and the cold water storage tank 46 via a sixteenth line 45. Water may travel between the cold water storage tank 46 and the molten salt-to-hot water heat exchanger 40 via an eighteenth line 47.

[0044] 3 shows a block diagram of a molten salt geothermal system with lithium extraction according to various embodiments. In one embodiment, the energy collection system is used to extract lithium from the brine fluid. After the brine fluid passes through the brine fluid-to-molten salt heat exchanger and before the brine fluid is reduced back into the resource, the brine fluid may go through a lithium extraction process.

[0045] As shown in FIG. 3, hot saltwater fluid may be sent from a production well 1 to a saltwater fluid to molten salt heat exchanger 10 via a first pipe 3. Cold molten salt may be stored in a cold molten salt storage chamber 14 and transferred to the saltwater fluid to molten salt heat exchanger 10 via a second pipe 19. Hot molten salt may move from the saltwater fluid to molten salt heat exchanger 10 to a hot molten salt storage chamber 12 via a third pipe 11. Hot molten salt may move from the hot molten salt storage chamber 12 to a molten salt to hot water for steam heat exchanger 20 via a fourth pipe 13.

[0046] The molten salt to hot water for steam heat exchanger 20 may generate steam for a steam turbine 50. The steam turbine 50 may rotate a rotor 51, which allows a generator 52 to provide electrical energy. A transformer 54 then converts the electrical energy to facilitate transmission of three-phase electricity 55 to the grid. The steam may travel from the steam turbine 50 to a condenser / cooling tower 23 via a fifth line 22, and from the condenser / cooling tower 23 to the molten salt to hot water for steam heat exchanger 20 via a sixth line 24. The molten salt may travel from the molten salt to hot water for steam heat exchanger 20 to a cold molten salt storage tank 14 via a seventh line 16.

[0047] The brine fluid from the brine fluid to molten salt heat exchanger 10 may travel to the lithium extractor 70 via an eighth line 5. From the lithium extractor 70, the brine fluid may travel to the reinjection well 2 via a ninth line 4.

[0048] In one embodiment, the energy harvesting system includes a magnetic lithium extractor configured to maintain pressure in a closed loop system. Although lithium can respond independently to magnetic forces, the response of lithium is relatively small compared to other metals. Dopants can be injected into the brine fluid to increase the magnetic response of lithium and thereby increase magnetic extraction. For example, the magnetic lithium extractor can inject iron into the brine fluid. Lithium is highly reactive and can form iron-doped compounds (e.g., iron-doped lithium oxide, iron-doped lithium titanium oxide, etc.). The lithium compounds can vary based on the composition of the brine fluid. A magnet can apply an attractive force to the iron-doped lithium compounds to draw them to the extraction well.

[0049] The extraction well may include two doors. During magnetic lithium collection, the closed-loop facing door may remain open and the outward facing door may remain closed. Once magnetic collection is complete, the closed-loop facing door closes to seal the iron doped lithium in the extraction well. Once the closed-loop facing door is closed, the outward facing door opens so that the collected iron doped lithium can be processed and purified. Because the closed-loop facing door and the outward facing door are not open at the same time, the pressure in the closed-loop system remains substantially constant.

[0050] One system may transfer heat from the brine fluid to molten salt, from the molten salt to steam, and from the steam to electricity. Another system may add a molten silicon or molten glass heat sink. Another system may add a thermal oil and hot water loop. Another system may add lithium extraction before reducing the brine fluid. The transfer of heat from the brine fluid to molten salt, from the molten salt to steam, and from the steam to electricity, the molten silicon or molten glass heat sink, the thermal oil and hot water loop, and the lithium extraction may be done simultaneously, one at a time, or in any combination thereof.

[0051] FIG. 4 illustrates a block diagram of an energy harvesting system, according to various embodiments. As shown in FIG. 4, the energy harvesting system may include one or more saltwater fluids from a well to saltwater fluid / molten salt heat exchanger 3. The saltwater fluids are sent to a saltwater fluid to molten salt heat exchanger 10 via a first line 4. Hot molten salt may travel between the saltwater fluid to molten salt heat exchanger 10 and a hot molten salt (MS) storage tank 12 via a second line 11. Cold molten salt may travel between the saltwater fluid to molten salt heat exchanger 10 and a cold molten salt storage tank 14 via a third line 19. The molten salt may travel between the hot molten salt storage tank 12 and a hot water to molten salt / steam heat exchanger 20 via a fourth line 13.

[0052] Hot water may travel from the hot water to molten salt / steam heat exchanger 20 and the generator set (GenSet) via a fifth line 21. The GenSet 50 may power a transformer 54. Water from the steam turbine may be sent to a condenser or cooling tower 23 via a sixth line 22 and sent back to the hot water to molten salt / steam heat exchanger 20 via a seventh line 24. The cold molten salt may be sent back to the cold molten salt storage tank 14 via an eighth line 16.

[0053] In one embodiment, the energy harvesting system may include a thermal vacuum chamber (TVC). A TVC is a vacuum chamber in which the radiant thermal environment is controlled. The controlled environment is created by removing air and other gases with a vacuum pump. By removing air and other gases, a low pressure and temperature controlled environment is created within the chamber with an efficient heat transfer mechanism.

[0054] 5 shows an isometric view of a brine fluid to molten salt geothermal thermal energy extraction system according to various embodiments, which may include a production well, a brine fluid to molten salt heat exchanger, one or more molten salt tanks, and a reinjection well.

[0055] The closed-loop brine fluid system extends from the production well, to the fluid-to-molten salt heat exchanger, and may extend through the reinjection well. The brine fluid moving through the closed-loop fluid system maintains a nearly constant pressure (e.g., the approximate pressure at the depth at which the brine fluid is extracted). The closed-loop brine fluid system includes a number of pumps for pumping the brine fluid through the system and maintaining the constant pressure. Because the pressure at the top of the closed-loop system is approximately equal to the pressure of the geothermal source, pumps may be used to induce movement of the brine fluid through the closed-loop system.

[0056] The speed control valve and pump maintain a substantially constant pressure between the top of the closed loop system and the geothermal source. The speed control valve and pump may be governed by sensors in the system as described above. For example, sensors may be located at the top of the closed loop system and in the geothermal source. If the sensors detect a change in pressure, the speed control valve and pump may be used to match the pressure. Additionally, the speed control valve and pump may be controlled simultaneously or separately, as desired.

[0057] A production well may be constructed in a previously drilled well (e.g., from previous fossil fuel extraction) or may be drilled at a new site. Conventional drilling techniques may be used to drill the well, such as, for example, reverse circulation drilling, diamond core drilling, direct push drilling, hydraulic rotary drilling, hydrothermal fracturing, or any combination thereof. After the well is drilled, a casing (e.g., titanium alloy casing) may be cemented in place by pumping cement into the annulus (e.g., the area between the casing and the surrounding rock formations). The casing may include a titanium alloy to reduce corrosion, particularly from corrosive brine fluids. The production casing and cement may prevent the production well from expanding or buckling under pressure from high pressure brine fluids. The casing may extend from the production zone of the geothermal source to the surface.

[0058] The production wells are used to extract brine fluids heated by the earth's natural heat. The geothermal fluids may contain hot water with total dissolved solids concentrations in excess of 350,000 ppm (approximately an order of magnitude higher than seawater). Conventional extraction techniques involve using a pressure differential between the geothermal source and the earth's surface to extract the geothermal fluids, which may convert the hot water to steam when it reaches the surface. The disclosed technology employs a closed loop system with near constant pressure, so the hot water may remain hot without turning into steam. The production wells may include a pump located near the earth's surface to extract the brine fluids from the geothermal source.

[0059] One or more molten salt tanks may store "cold" molten salt (i.e., molten salt before entering the heat exchanger) and "hot" molten salt (i.e., molten salt after leaving the heat exchanger). In one embodiment, a single molten salt tank may be used with a divider between the cold molten salt storage compartment and the hot molten salt. The divider may comprise a non-thermally conductive material, such as, for example, manganese, basalt fiber, or a basalt coating. For example, the divider may comprise a first manganese layer, an air gap, and a second manganese layer.

[0060] In one embodiment, separate molten salt tanks may be used to store the cold and hot molten salts separately. The walls of the storage vessel may include a substantially thermally non-conductive material, such as, for example, manganese, basalt fiber, or a basalt coating. The storage vessel may include an insulating layer sandwiched between one or more other layers. The insulating layer may include, for example, a gas (e.g., air), ceramic fiber, mineral wool, or any combination thereof.

[0061] The cooled brine fluid after leaving the heat exchanger may be returned to the geothermal formation via an injector well. Returning the brine fluid to the geothermal formation may help maintain reservoir pressure and ensure that the thermal energy resource is not depleted. The injector well may be formed using similar technology as that used in the production well. The injector well may include one or more pumps to pump the brine fluid to the geothermal formation. Because the pressure of the brine fluid is approximately equal to the geothermal formation, the energy required to pump the fluid back to the formation may be significantly less than conventional technology.

[0062] The system described herein may be illustrated in Figure 5. As illustrated in Figure 5, the industrial park may include any of the following: silicon carbide / boron carbide plant 80, steel forging / metal recycling / glass recycling 90, basalt fiber plant 100, ceramic plant 110, brick plant 120, tile plant 130, isoprene plant 140, desalination plant 150, waste recycling and algae to bio-oil pyrolysis plant 160, textile plant 170, automotive kiln for dried paint 180, dehydration plant 190, food processing plant 200, bakery 210, cold storage / ice plant 220, algae farm 230, tilapia farm 240, beverage manufacturing plant 250.

[0063] FIG. 6 is an isometric view of an industrial park substantially powered by geothermal energy, according to various embodiments. The geothermal energy may provide energy to, for example, a steam generator. The industrial park also includes a closed-loop molten salt distribution system. The industrial park may include components such as production wells, reinjection wells, a saltwater fluid to molten salt heat exchanger, and a molten salt to water heat exchanger. In addition, substantially all of the energy required to power the industrial park may be generated within the industrial park. For example, energy generated by a steam generator may be used to power the industrial park's infrastructure (e.g., lighting, temperature control, etc.).

[0064] In one embodiment, to maximize energy production and energy efficiency in an industrial park, sand, firebricks, and iron alloy materials may be incorporated into the building materials of the park. For example, heat exchangers may be made of iron alloy materials, piping may be insulated with sand, and any elements (e.g., piping) that run along or below ground may be surrounded by firebricks.

[0065] A system for delivering salt to an end user in piping 66, 67 as described herein may be shown in Figure 6. As shown in Figure 6, the industrial park may include any of the following: silicon carbide / boron carbide plant 80, steel forging / metal recycling / glass recycling 90, basalt fiber plant 100, ceramic plant 110, brick plant 120, tile plant 130, isoprene plant 140, desalination plant 150, waste recycling and algae to bio-oil pyrolysis plant 160, textile plant 170, automotive kiln for dried paint 180, dewatering plant 190, food processing plant 200, bakery 210, cold storage / ice plant 220, algae farm 230, and tilapia farm 240.

[0066] FIG. 7 illustrates a block diagram of a system for extracting energy from geothermal brine fluid, according to various embodiments. The brine fluid may be extracted from a production well 1 and a brine fluid manifold 5 with six production wells via a brine fluid 3 from well-to-manifold piping. The brine fluid is routed from the brine fluid manifold 5 with six production wells via a brine fluid inlet pipe to a brine fluid molten salt heat exchanger 7 to a brine fluid to molten salt heat exchanger 10. The hot brine fluid is routed from the brine fluid to molten salt heat exchanger 10 via a brine fluid to molten salt heat exchanger to hot molten salt storage chamber piping 11 to a hot molten salt storage tank 12. The hot molten salt is routed from the hot molten salt storage tank 12 via a hot molten salt storage pipe to hot water for molten salt / steam heat exchanger 13 to a hot water for molten salt / steam heat exchanger 20.

[0067] Hot water may travel from molten salt / steam hot water heat exchanger 20 to generator set (GenSet) 50 via steam piping 21 to the GenSet. GenSet 50 may power rotor 51 and generator 52, which may provide power 53 to transformer 54 and high voltage conduit 55 to the transformer and end users.

[0068] Conduit 55 may power any of silicon carbide / boron carbide plants 80, steel forging / metal recycling / glass recycling 90, basalt fiber plant 100, ceramic plant 110, brick plant 120, tile plant 130, isoprene plant 140, desalination plant 150, waste recycling and algae to bio-oil pyrolysis plant 160, textile plant 170, automotive kiln for drying paint 180, dehydration plant 190, food processing plant 200, bakery 210, refrigeration / ice plant 220, algae farm 230, tilapia farm 240, and beverage manufacturing plant 250.

[0069] Hot water may be sent from the generator 50 to the condenser or cooling tower 23 via piping 22 that carries the hot water from the steam turbine to the condenser or cooling tower. Cold water may be sent from the condenser or cooling tower 23 to the hot water for molten salt / steam heat exchanger 20 via cold water 24 back to the hot water for molten salt / steam heat exchanger.

[0070] The molten salt may be sent from the hot water heat exchanger 20 for molten salt / steam via piping 15 from the molten salt to steam heat exchanger to the heat oil heat exchanger to the molten salt / heat oil heat exchanger 30. The heat oil may be sent from the molten salt / heat oil heat exchanger 30 via piping 31 from the hot heat oil to hot heat oil storage tank to the hot heat oil storage tank to the heat oil system to the heat oil system 32 to the heat oil system 34 to the end user 35. The heat oil may be sent to the cold heat oil storage tank 38 via cold heat oil return piping 36 and from the heat oil system to the cold heat oil storage tank return piping 37. The thermal oil may be routed from the cold thermal oil storage chamber to the molten salt / hot water heat exchanger 40 via a return line 39 to the molten salt / oil heat exchanger.

[0071] Hot water may be sent from the molten salt / hot water heat exchanger 40 via piping 41 from the molten salt / hot water to the hot water storage tank to the hot water storage tank 42 and via piping 43 from the hot water storage tank to the hot water system to the hot water system 44. Water may be sent from the system via piping hot water to the end user 45 and from the end user via return water to the hot water system 46. Cold water may be sent via cold water return piping 47 to the cold water storage tank to the cold water storage tank 48 and from the cold water storage tank via return piping 49 to the molten salt / hot water heat exchanger 40.

[0072] The molten silicon may be delivered from the molten silicon to molten salt heat exchanger 60 via piping 61 from the molten silicon storage chamber to the molten silicon / molten salt heat exchanger to the molten silicon return line 62 to the molten silicon storage chamber. The molten salt may be delivered from hot molten salt piping 63 to the molten silicon / molten salt heat exchanger to the cold molten salt return line 64 from the end user to the molten salt / molten silicon heat exchanger. The system may include a molten silicon storage chamber with a heating electrode 65 where the hot molten salt is delivered via hot molten salt distribution piping 66 to the end user and returned via cold molten salt return line 67 from the end user.

[0073] The cold molten salt may be stored in a cold molten salt storage tank 14. The molten salt may be sent from the molten salt / thermal oil heat exchanger via piping 17 to the molten salt / hot water heat exchanger and from the molten salt / water heat exchanger to the cold molten salt storage chamber via piping 18, and returned from the cold molten salt storage chamber to the salt water fluid / molten salt heat exchanger via return piping 19 to the salt water fluid to molten salt heat exchanger 10. The salt water fluid may be sent from the salt water fluid / molten salt heat exchanger to the salt water fluid manifold 6 via piping 8 to the reinjection wells 2, and from the manifold to the reinjection wells via the salt water fluid to the reinjection wells 4.

[0074] FIG. 8 illustrates a block diagram of a geothermal heat extraction management system, according to various embodiments. As shown in FIG. 8, the system may include a first pressure sensor 1 disposed in a geothermal source and configured to detect a first pressure. The system may include a pump 2 disposed in an extraction well and a second pressure sensor 3 disposed in the extraction well to detect a second pressure. The system may include a heat exchanger 4 configured to transfer heat between the brine fluid and the molten salt. The system may include a processor 5 connected to the pump and the heat exchanger. The processor 5 may be configured to analyze a difference in pressure readings between the first pressure sensor and the second pressure sensor and to instruct the pump to adjust the first pressure in the extraction well to match the second pressure in the geothermal source by increasing or decreasing the flow rate of the brine fluid inside the extraction well.

[0075] The system may include a pressure sensor 6 for connecting to both the first and second pressure sensors 1,3, a lifting suspension cable 7 for the pump and the sensor, and an electrical cable 8 for the pump.

[0076] 9 is a block diagram illustrating a method for collecting thermal energy from a saltwater fluid, according to various embodiments. The method may include receiving saltwater fluid from a geothermal source via a production well through a first set of heat exchangers (block 902).

[0077] The method may include transferring thermal energy from the saltwater fluid to the molten salt with a first set of heat exchangers, where the saltwater fluid remains in the closed loop system separate from the molten salt (block 904).

[0078] The method may include pumping the molten salt to a hot molten salt storage tank (block 906).

[0079] The method may include returning the saltwater fluid to the geothermal source via the reinjection well (block 908).

[0080] In some embodiments, the method includes transferring the molten salt from a storage tank of hot molten salt to a second set of heat exchangers configured to power a steam turbine.

[0081] In some embodiments, the molten salt converts water to steam via a second set of heat exchangers, and the steam spins a turbine.

[0082] In some embodiments, the steam is sent to a condenser and a cooling tower.

[0083] In some embodiments, the steam is condensed and returned to the turbine as water to receive thermal energy from a second set of heat exchangers.

[0084] In some embodiments, the molten salt heated by thermal energy transferred from the saltwater fluid is delivered to one or more areas within the industrial park.

[0085] In some embodiments, the molten salt, after releasing the thermal energy to the industrial park, is returned to the first set of heat exchangers to cause the molten salt to repeat the transfer of thermal energy from the saltwater fluid to the molten salt.

[0086] In some embodiments, the first set of heat exchangers controls the velocity of the saltwater fluid.

[0087] In some embodiments, the saltwater fluid comprises a temperature between about 195°C and 800°C.

[0088] In some embodiments, the flow rate of the molten salt is controlled by a rate control valve and a pump.

[0089] In some embodiments, the flow rate of the molten salt is monitored by sensors that provide feedback to the speed control valves and pumps, thereby maintaining a maintained pressure approximately equal to the pressure inside the geothermal source.

[0090] In some embodiments, the molten salt is mixed with the nanoparticles.

[0091] In some embodiments, the molten salt and brine fluids are separated by a basalt-based partition.

[0092] In another embodiment, a method for collecting thermal energy from a saltwater fluid includes receiving saltwater fluid from a production well by a first set of heat exchangers. The method also includes transferring thermal energy from the saltwater fluid to molten salt by the first set of heat exchangers, the saltwater fluid remaining separate from the molten salt in the first closed loop system. The method also includes pumping the molten salt to a hot molten salt storage tank. The method also includes transferring thermal energy from the molten salt to a thermal fluid by a second set of heat exchangers, the molten salt remaining separate from the thermal fluid in the second closed loop system. The method also includes returning the saltwater fluid to a geothermal source via an injection well.

[0093] In some embodiments, a second set of heat exchangers exchanges thermal energy from the molten salt to the thermal oil.

[0094] In some embodiments, a second set of heat exchangers exchanges thermal energy from the molten salt to water. A maintenance pressure approximately equal to the pressure inside the geothermal source is maintained by a speed control valve and a pump.

[0095] In some embodiments, the maintained pressure is read by a sensor that provides feedback to the speed control valve and pump.

[0096] In another embodiment, a method for collecting thermal energy from a saltwater fluid includes receiving saltwater fluid from a production well by a first set of heat exchangers. The method also includes transferring thermal energy from the saltwater fluid to molten salt by the first set of heat exchangers, the saltwater fluid remaining in a first closed loop system separate from the molten salt. The method also includes pumping the molten salt to a hot molten salt storage tank. The method also includes transferring thermal energy from the molten salt to molten silicon or molten glass by a second set of heat exchangers, the molten salt remaining in a second closed loop system separate from the molten silicon or molten glass. The method also includes returning saltwater fluid to a geothermal source via a reinjection well.

[0097] In some embodiments, the second set of heat exchangers includes electrodes that use energy generated in the second closed loop system.

[0098] In some embodiments, a maintenance pressure approximately equal to the pressure inside the geothermal source is maintained by a speed control valve and pump.

[0099] In some embodiments, the maintained pressure is read by a sensor that provides feedback to the speed control valve and pump.

[0100] In some embodiments, the method includes transferring thermal energy from the molten salt to electrical energy by a second set of heat exchangers, and transferring thermal energy from the molten salt to the molten silicon or molten glass includes heating the molten silicon or molten glass using an electrical resistance coil containing electrical energy.

[0101] In some embodiments, the state of the molten silicon or molten glass includes liquid or solid, and either the molten silicon or molten glass is mixed with the nanoparticles.

[0102] In another embodiment, a geothermal collector includes a heat exchanger configured to transfer thermal energy between a brine fluid and molten salt, where the brine fluid is drawn from a geothermal aquifer through a production well, where the brine fluid remains separate from the molten salt in a closed loop system, where the closed loop system extends from the production well to an injector well. The apparatus also includes a molten salt storage tank configured to receive the molten salt heated by the heat exchanger. The apparatus also includes an injector well configured to return the brine fluid to the geothermal aquifer, where the closed loop system maintains a substantially constant pressure from the production well to the injector well.

[0103] In another embodiment, a geothermal heat extraction management system includes a pump disposed in an extraction well. The system also includes a first pressure sensor disposed in the geothermal source. The system also includes a second pressure sensor disposed in the extraction well. The system also includes a heat exchanger configured to transfer thermal energy between the brine fluid and the molten salt. The system also includes a processor connected to the pump and the heat exchanger, the processor configured to analyze a difference in pressure readings between the first pressure sensor and the second pressure sensor and to instruct the pump to adjust the first pressure in the extraction well to match the second pressure in the geothermal source by increasing or decreasing a flow rate of the brine fluid within the extraction well.

[0104] In addition to the above examples, various other modifications and alterations of the present invention may be made without departing from the present invention. Accordingly, the above disclosure should not be deemed limiting, and the appended claims should be construed to encompass the true spirit and full scope of the present invention.

Claims

1. 1. A method for generating electrical power from a geothermal well, comprising: heating the brine fluid in the geothermal well; transferring saltwater fluid thermal energy from the saltwater fluid to molten salt, the saltwater fluid remaining separate from the molten salt within a closed fluid loop system, the saltwater fluid maintaining a substantially constant pressure within the closed fluid loop system that matches the pressure within the geothermal well; heating the molten salt to a higher operating temperature using molten silicon in a molten silicon heat exchanger; pumping the molten salt to a turbine system; transferring molten salt thermal energy from the molten salt to the turbine system, the molten salt remaining in a closed salt loop system separate from the turbine system; A method comprising:

2. The method of claim 1 , wherein the saltwater fluid thermal energy is transferred from the saltwater fluid to the molten salt by a first set of heat exchangers.

3. The method of claim 1 , further comprising pumping the molten salt from the turbine system to a molten salt storage tank.

4. the turbine system includes a closed steam loop system; 2. The method of claim 1, further comprising: using the molten salt thermal energy to convert water to steam in the turbine system via a second set of heat exchangers, the steam rotating a turbine.

5. The method of claim 4 further comprising the step of directing the steam to a condenser cooled by a cooling tower.

6. collecting cooled water from the condenser and the cooling tower; returning the cooled water to the second set of heat exchangers. The method of claim 5 further comprising:

7. 1. A system for collecting thermal energy from a geothermal well, comprising: a brine fluid that is heated by a geothermal well and maintains a substantially constant pressure in a closed fluid loop system that matches the pressure in the geothermal well; Molten salt; a first set of heat exchangers for transferring saltwater fluid thermal energy from the saltwater fluid to the molten salt; a molten silicon heat exchanger that uses molten silicon to heat the molten salt to a higher operating temperature; A turbine system including a steam closed loop system, in which molten salt thermal energy is used to produce electricity; A system equipped with

8. The system of claim 7 , wherein the saltwater fluid is in a saltwater fluid closed loop system.

9. the molten salt is in a molten salt closed loop system; the saltwater fluid closed loop system is separate from the molten salt closed loop system; The system of claim 8 , wherein the saltwater fluid closed loop system and the molten salt closed loop system are separate from the turbine system.

10. 8. The system of claim 7, further comprising a molten salt storage tank, into which the molten salt is transferred after the molten salt thermal energy has been used to produce electricity.

11. a second set of heat exchangers that converts water to steam using the molten salt thermal energy from the molten salt; a turbine, the steam rotating the turbine; The system of claim 7 further comprising:

12. Condenser and a cooling tower, the steam being delivered to the condenser where it is cooled by the cooling tower; The system of claim 11 further comprising:

13. 13. The system of claim 12, wherein chilled water is collected from the condenser and the cooling tower, and the chilled water is circulated to the second set of heat exchangers.

14. 1. A method for generating electrical power from a geothermal well, comprising: circulating a brine fluid within the geothermal well, the brine fluid maintaining a substantially constant pressure within a closed fluid loop system that matches the pressure within the geothermal well; transferring saltwater fluid thermal energy from said saltwater fluid to molten salt using a first set of heat exchangers; heating the molten salt to a higher operating temperature using molten silicon in a molten silicon heat exchanger; transferring molten salt thermal energy from the molten salt to a turbine system using a second set of heat exchangers; Including, The method wherein the molten salt thermal energy is used by the turbine system to generate electrical power.

15. 15. The method of claim 14, wherein the saltwater fluid is separated from the molten salt in a closed loop system.

16. 15. The method of claim 14, wherein the geothermal well is a pre-drilled well previously constructed for purposes other than geothermal energy production.

17. 15. The method of claim 14, wherein the saltwater fluid is returned into the geothermal well after passing through the first set of heat exchangers.

18. The method of claim 1 or claim 14, wherein the nanoparticles are added to the molten salt at any point in the closed loop system.

19. The method of claim 19, further comprising the step of reducing the saltwater fluid back into the resource; 15. The method of claim 1 or claim 14, wherein after the step of transferring brine fluid thermal energy from the brine fluid to the molten salt and before the step of reducing the brine fluid back into the resource, the brine fluid is passed through a lithium extraction process to extract lithium from the brine fluid.

20. The system of claim 7, wherein the nanoparticles are added to the molten salt at any point in the closed loop system.

21. A method for extracting lithium from a saltwater fluid, comprising:

8. The system of claim 7, wherein the brine fluid passes through a lithium extraction process after passing through the first heat exchanger and before the brine fluid is reduced back into the resource.

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