Geothermal power generation from ultra-high temperature geothermal fluids and magma reservoirs

Abstract

Systems, methods and apparatus for harnessing geothermal power generation from ultra-high temperature geothermal fluid (SHGF) and magma reservoirs. An exemplary apparatus may include a well screen coupled to an end of a casing string. The well screen, at least partially immersed in the underground reservoir, is coaxially aligned with the well screen and configured to be repositioned relative to the well screen. A draw pipe extending through the slidable casing is configured to convey the SHGF from the underground reservoir toward the surface in response to the slidable casing being repositioned to block more of a set of apertures in the well screen and an increase in pressure within the cavity of the slidable casing.

Description

[Technical field]

[0001] CROSS-REFERENCE TO RELATED APPLICATIONS This application is based on and claims the benefit of: (1) U.S. Patent Application No. 18 / 099,499, filed January 20, 2023, which claims priority to U.S. Provisional Patent Application No. 63 / 315,063, filed February 28, 2022; (2) U.S. Patent Application No. 18 / 099,509, filed January 20, 2023, which claims priority to U.S. Provisional Patent Application No. 63 / 315,063, filed February 28, 2022; (3) U.S. Patent Application No. 18 / 099,514, filed January 20, 2023, which claims priority to U.S. Provisional Patent Application No. 63 / 315,063, filed February 28, 2022; and (4) U.S. Provisional Patent Application No. This application claims priority to U.S. patent application Ser. No. 18 / 099,518, filed Jan. 20, 2023, which claims priority to U.S. patent application Ser. No. 63 / 315,063. [Background technology]

[0002] Aspects of the present disclosure relate to geothermal power generation systems and associated methods, and more particularly, to systems and methods for generating geothermal power from subsurface resources such as reservoirs of magma.

[0003] Solar and wind power are the most commonly available renewable energy sources, but both are notoriously unreliable and have relatively poor power density. In contrast, geothermal energy has a high power density and can operate regardless of weather conditions or time of day. Summary of the Invention [Problem to be solved by the invention]

[0004] However, geothermal energy substitution is not realistic due to the lack of necessary technological advances. [Means for solving the problem]

[0005] One or more aspects of the present disclosure are directed to a pumping apparatus for a SHGF system. The pumping apparatus comprises a well screen coupled to an end of a casing string. The well screen, at least partially immersed in the subterranean reservoir, defines a volume of the subterranean reservoir configured to be at least partially filled with SHGF through a set of apertures in the well screen. The pumping apparatus further comprises a slideable casing having a first end and a second end. The slideable casing defines an opening at the first end that opens into a cavity bounded by a sidewall and an end wall at the second end. Additionally, the slideable casing is suspended within the borehole and coaxially aligned with the well screen. The pumping apparatus further comprises a draw pipe extending through the end wall of the slideable casing and into the volume defined by the well screen. The draw pipe is configured to transport the SHGF from the underground reservoir toward the surface in response to the slidable casing being slidably repositioned to block more of the set of apertures in the well screen and in response to an increase in pressure within the cavity of the slidable casing.

[0006] One or more aspects of the present disclosure are also directed to a method for operating a pumping device for a SHGF system. The method includes a first step of repositioning a slideable casing in a borehole from an initial position between the surface and the underground reservoir to a final position at least partially within the underground reservoir. The slideable casing has an opening at a first end that opens into a cavity bounded by a sidewall and an end wall at a second end. The slideable casing is coaxially aligned with a well screen at the end of the casing string and is at least partially immersed in the underground reservoir, the well casing comprising a set of apertures that allow the inflow of SHGF into a volume defined by the well screen. In the final position, the cavity of the slideable casing substantially coincides with the volume defined by the well screen to prevent flow of SHGF through the set of apertures, and the cavity is filled with SHGF from the volume defined by the well screen. The method includes the further steps of fixing the slidable casing in a final position within the borehole, increasing pressure within the cavity of the slidable casing to cause SHGF within the cavity to flow into a draw pipe that extends through an end wall of the slidable casing and into the cavity, and conveying the SHGF through the draw pipe to the surface.

[0007] One or more aspects of the present disclosure are also directed to a system for generating electrical power from an underground reservoir of magma. The system includes a steam separator directly connected to a cased wellbore extending between the earth's surface and the underground reservoir of magma. The steam separator separates the gas phase fluid from a condensate formed from the gas phase fluid. The system further includes a first set of turbines connected to the steam separator and a condensate tank fluidly connected to the steam separator and the first set of turbines. The first set of turbines is configured to generate electricity from the gas phase fluid received from the steam separator, and the condensate tank is fluidly connected to a fluid conduit that supplies the condensate to a terminal of the cased wellbore.

[0008] Aspects of the present disclosure are also directed to a method for generating electrical power from an underground reservoir of magma. The method includes a first step of supplying a liquid-phase fluid to a casing wellbore extending from the earth's surface to the underground reservoir of magma. Heat provided from the magma transforms the liquid-phase fluid into a gas-phase fluid that is transported up the casing wellbore to the earth's surface. The method further includes separating the gas-phase fluid from a condensate formed from the gas-phase fluid, operating a set of turbines with the gas-phase fluid to generate electricity, accumulating at least a portion of the condensate formed from the gas-phase fluid, and supplying the accumulated condensate to the casing wellbore as a liquid-phase fluid.

[0009] Aspects of the present disclosure are also directed to a cased well for use in generating power from an underground reservoir of magma. The cased well comprises a well casing suspended in a borehole extending between the earth's surface and the underground reservoir of magma, and a boiler casing housed within the well casing and extending between the earth's surface and the underground reservoir of magma. The boiler casing has a first end immersed in the underground reservoir of magma and a terminal opposite the first end. The cased well further comprises a fluid conduit housed within the boiler casing and configured to deliver a liquid-phase fluid to the terminal of the boiler casing. The temperature and pressure at the terminal of the boiler casing convert the liquid-phase fluid to a gas-phase fluid that travels through the boiler casing to the earth's surface. The cased well further comprises a wellhead connected to the first end of the boiler casing.

[0010] Aspects of the present disclosure are also directed to a method of forming a cased well bore for use in generating power from an underground reservoir of magma. The method includes drilling a well bore from the earth's surface into the underground reservoir of magma, suspending a well casing within the well bore, responsive to the well bore reaching a target depth, suspending a boiler casing within the well casing, and resuming drilling of the well bore from the target depth to a final depth within the underground reservoir of magma. The boiler casing extends from the earth's surface to the final depth within the underground reservoir to form the cased well bore.

[0011] One or more aspects of the present disclosure are also directed to a cased wellbore for use in generating superheated steam. The cased wellbore includes a first end at the earth's surface, a second end at an underground reservoir of magma, and a fluid passageway extending from an inlet at the first end to the second end and then from the second end to an outlet at the first end. The fluid passageway is configured to receive saturated steam at the inlet and discharge superheated steam at the outlet, where the saturated steam is converted to superheated steam at the second end of the cased wellbore.

[0012] One or more aspects of the present disclosure are also directed to a system for generating electricity using superheated steam. The system includes a casing wellbore extending between the earth's surface and an underground reservoir of magma. The casing wellbore includes a first end at the earth's surface, a second end at the underground reservoir of magma, and a fluid passageway extending from an inlet at the first end to the second end and then from the second end to an outlet at the first end. The fluid passageway is configured to receive saturated steam at an inlet and to discharge superheated steam at an outlet. The saturated steam is converted to superheated steam in the fluid passageway at the second end of the casing wellbore. The system further includes a set of turbines configured to generate electricity from the superheated steam provided by the casing wellbore.

[0013] One or more aspects of the present disclosure are also directed to a method for generating electricity using superheated steam. The method includes receiving saturated steam from a steam source and conveying the saturated steam into a casing wellbore extending from the earth's surface to an underground reservoir of magma to expose the saturated steam to heat from the underground reservoir of magma. The heat from the underground reservoir of magma converts the saturated steam to superheated steam. The method further includes conveying the superheated steam back toward the earth's surface.

[0014] Other aspects, embodiments and features of the present disclosure will become apparent from the following detailed description of the present disclosure when considered together with the accompanying drawings, in which identical or substantially similar components shown in various figures are each represented by a single number or symbol. For clarity, not all components are given reference numbers in all figures. Not all components of each embodiment of the present disclosure are shown unless illustration is necessary to enable a person skilled in the art to understand the present disclosure.

[0015] The features believed characteristic of the present disclosure are set forth in the appended claims, however the disclosure itself, as well as the preferred modes of use, further objects and advantages thereof, can best be understood by reference to the following detailed description of illustrative embodiments, read in conjunction with the accompanying drawings. [Brief description of the drawings]

[0016] [Figure 1] 1 is a cross-sectional view of a portion of the earth illustrating subsurface formations that may be exploited to generate geothermal power in accordance with an illustrative embodiment; [Figure 2A] FIG. 1 is a diagram showing a conventional geothermal power generation system. [Figure 2B] FIG. 1 illustrates a theoretical Very High Temperature Geothermal System (SHGS). [Figure 2C] FIG. 1 illustrates a magma-based geothermal power generation system ("Magma System") in accordance with an illustrative embodiment. [Diagram 3]FIG. 2C is a cross-sectional view of a conventional well for use with the theoretical SHGS of FIG. [Figure 4A] 2C through 2D are cross-sectional views of various portions of a well for use with the theoretical SHGS of FIG. 2B in accordance with one or more embodiments of the present disclosure. [Figure 4B] 2C through 2D are cross-sectional views of various portions of a well for use with the theoretical SHGS of FIG. 2B in accordance with one or more embodiments of the present disclosure. [Figure 5A] 1A-1D are various views of a pneumatic collar seal according to an exemplary embodiment; [Figure 5B] 1A-1D are various views of a pneumatic collar seal according to an exemplary embodiment; [Figure 5C] 1A-1D are various views of a pneumatic collar seal according to an exemplary embodiment; [Figure 6] 2D is a cross-sectional view of a cased well for use with the magma system of FIG. 2C according to an exemplary embodiment. [Figure 7A] 7A-7D are various views of a first end, or top, of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 7B] 7A-7D are various views of a first end, or top, of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 8A] 7A-7C are various views of a fluid injection conduit of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 8B] 7A-7C are various views of a fluid injection conduit of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 9A] 7A-7D are various views of a second end, terminus, of the cased well of FIG. 6 in accordance with an illustrative embodiment. [Figure 9B] 7A-7D are various views of a second end, terminus, of the cased well of FIG. 6 in accordance with an illustrative embodiment. [Figure 10A] 7A-7D are various views of a wellhead of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 10B] 7A-7D are various views of a wellhead of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 10C]7A-7D are various views of a wellhead of the cased well of FIG. 6 in accordance with an exemplary embodiment. [Figure 11A] 7A-7C are various views of a vent cap for use with the cased well of FIG. 6 in accordance with an illustrative embodiment. [Figure 11B] 7A-7C are various views of a vent cap for use with the cased well of FIG. 6 in accordance with an illustrative embodiment. [Figure 11C] 7A-7C are various views of a vent cap for use with the cased well of FIG. 6 in accordance with an illustrative embodiment. [Figure 12] FIG. 1 illustrates a simplified diagram of a magma system in accordance with an illustrative embodiment. [Figure 13] FIG. 1 is a diagram of a set of turbines for use in a magma system according to an illustrative embodiment. [Figure 14A] 1 is a perspective view of a drill bit for use in drilling a well for a magma system according to an illustrative embodiment; [Figure 14B] 1 is a perspective view of a drill bit for use in drilling a well for a magma system according to an illustrative embodiment; [Figure 15A] 1A-1D are various views of a drill system for use in drilling a well for a magma system in accordance with an illustrative embodiment; [Figure 15B] 1A-1D are various views of a drill system for use in drilling a well for a magma system in accordance with an illustrative embodiment; [Figure 16] FIG. 1 is an illustration of a system for generating superheated steam in accordance with an illustrative embodiment. [Figure 17A] 1 is a schematic diagram of a downstream well for generating superheated steam according to an illustrative embodiment; FIG. [Figure 17B] 1 is a schematic diagram of a downstream well for generating superheated steam according to an illustrative embodiment; FIG. [Figure 17C] 1 is a schematic diagram of a downstream well for generating superheated steam according to an illustrative embodiment; FIG. [Figure 18]FIG. 17B is a cross-sectional view of a boiler casing for use with the downstream well of FIG. 17A according to an exemplary embodiment. [Figure 19A] 17B is a schematic diagram of a boiler casing for use with the downstream well of FIG. 17A according to an exemplary embodiment; [Figure 19B] 17B is a schematic diagram of a boiler casing for use with the downstream well of FIG. 17A according to an exemplary embodiment; [Figure 20] 1 is a flow diagram of a method for pumping very high temperature geothermal fluid (SHGF) through a cased well in accordance with an illustrative embodiment. [Figure 21] 1 illustrates a flowchart of a method for generating power with a magma system in accordance with an illustrative embodiment. [Figure 22] 1 is a flow diagram of a method for forming a cased well bore in accordance with an illustrative embodiment. [Figure 23] 1 is a flow diagram of a method for suspending a boiler casing according to an illustrative embodiment. [Figure 24] 1 is a flow diagram of a method for inserting a boiler casing into a well casing contained within a well bore in accordance with an illustrative embodiment. [Diagram 25] 1 is a flow diagram of a method for transporting a boiler casing through a well casing and into a wellbore in accordance with an illustrative embodiment. [Figure 26] 1 illustrates a flow diagram for generating superheated steam according to an illustrative embodiment. [Figure 27A] 1A-1D are various views of a well for generating superheated steam in accordance with another illustrative embodiment; [Figure 27B] 1A-1D are various views of a well for generating superheated steam in accordance with another illustrative embodiment; [Figure 27C] 1A-1D are various views of a well for generating superheated steam in accordance with another illustrative embodiment; [Figure 28A] 27A-27C are various views of a boiler casing for a well 2700 in accordance with an illustrative embodiment; [Figure 28B]27A-27C are various views of a boiler casing for a well 2700 in accordance with an illustrative embodiment; [Figure 28C] 27A-27C are various views of a boiler casing for a well 2700 in accordance with an illustrative embodiment; [Figure 29] FIG. 4 is a more detailed view of a casing plate installed in an upper portion of a wellbore in accordance with an illustrative embodiment; [Diagram 30] FIG. 30 is a plan view of the casing plate of FIG. 29. [Diagram 31] FIG. 1 is a cross-sectional view of a casing plate arm in accordance with an illustrative embodiment. [Diagram 32] FIG. 1 is a cross-sectional view of an arm of a casing plate installed between two segments of a boiler casing according to an exemplary embodiment. [Figure 33A] FIG. 4 is a more detailed view of a casing plate in accordance with an illustrative embodiment; [Figure 33B] FIG. 4 is a more detailed view of a casing plate in accordance with an illustrative embodiment; [Diagram 34] FIG. 13 is a diagram of a casing plate according to another exemplary embodiment. [Figure 35A] 11A-11C are various views of a casing plate according to yet another exemplary embodiment; [Figure 35B] 11A-11C are various views of a casing plate according to yet another exemplary embodiment; [Diagram 36] 1 is a simplified schematic diagram of another Magma power system in accordance with an illustrative embodiment; [Figure 37] 1 is a schematic diagram of a superheated steam system according to an exemplary embodiment; [Figure 38A] FIG. 2 is a cross-sectional view of a well for generating superheated steam according to another illustrative embodiment. [Figure 38B] FIG. 2 is a cross-sectional view of a well for generating superheated steam according to another illustrative embodiment. [Figure 39] FIG. 1 is a cross-sectional view of a spacer installed in a wellbore having a corrugated second casing. DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS

[0017] Geothermal power is generated by complex systems that can require significant expenditures of capital, manpower, and equipment. Furthermore, most conventional geothermal systems utilize low temperature resources, such as low temperature geothermal water, below 194° F., and have low power output. The inability to access high temperature geothermal resources reliably and efficiently makes conventional geothermal systems financially impractical.

[0018] One or more aspects of the present disclosure are based on the following unexpected observations.

[0019] The depth of the magma can be relatively shallow, about 2.1 to 2.5 km.

[0020] The top layer of magma has few crystals and no mush zone.

[0021] Rocks are not ductile and can support fractures.

[0022] No degradation of heat output over a two-year period.

[0023] Eruptions at the drill sites are unlikely (e.g., the drill sites in Africa and Iceland have not erupted for over 10,000 years, and the Kilauea drill site in Hawaii is thought to have never erupted).

[0024] Drilling down to the magma is fairly safe, and the rising magma can be cooled with water to form a plug.

[0025] Some aspects of the present disclosure recognize the need for a geothermal power generation system that utilizes geothermal resources that are hot enough to provide high temperature, high pressure steam, thereby avoiding the challenges associated with conventional wells that must deal with low permeability. Geothermal water is contained within rocks, and permeability is important for sufficient geothermal water flow to meet demand.

[0026] 1 is a partial cross-sectional view of the Earth illustrating subsurface formations that may be exploited to generate geothermal power according to an exemplary embodiment. Geothermal energy originates from deep within the Earth. The Earth's composition is made up of an inner core 102, an outer core 104, a lower mantle 106, a transition zone 108, an upper mantle 110, and a crust 112. There are places in the Earth where magma reaches the surface of the crust 112 and forms volcanoes 114. In most cases, the magma comes within a few miles of the Earth's surface, creating enough groundwater for geothermal power generation.

[0027] Pure water has a total dissolved solids (TDS) concentration of 0 ppm. Laboratory and pharmaceutical grade water has a TDS of less than 10 ppm. Public drinking water in the United States is generally less than 100 ppm, and seawater is between 22,000-29,000 ppm. Relatively clean geothermal resources have a TDS of 6,000-7,000 ppm, but are often much higher. For comparison, the geothermal waters of the Salton Sea in California have a TDS of over 240,000 ppm. The high TDS content may be due to the high heat and pressure that chemically dissociates the rocks into water. This results in geothermal fluids that are polybaric, amphoteric, have both acidic and alkaline properties, and have a high TDS. This can cause premature failure of geothermal equipment such as well screens, motors, and pumps due to corrosion or blockage by scaling caused by calcium carbonate, etc.

[0028] Geothermal waters are also rich in dissolved gases such as carbon dioxide and sulfur dioxide, both greenhouse gases that can cause acid rain. These dissolved gases cause pressure drops and must be removed from the steam before it reaches the turbine. Incomplete gas removal can cause corrosion of the turbine blades, which must then be specially treated to resist corrosion. In fact, due to the high TDS and gas concentrations in geothermal waters and the relatively low heat of geothermal waters (300-450°F), 70% of all water pumped to the surface is never used for steam going to the turbines, but is rejected and pumped back to the injection wells. This, combined with the numerous parasitic loads from having to source multiple wells and separate solids, liquids, and gases due to the low temperatures, results in low efficiencies of 5-12%. Some plants have been shut down due to excessive parasitic loads combined with reduced thermal output.

[0029] FIG 2A illustrates a geothermal power generation system. Geothermal system 200a is a "flash plant" that generates electricity from high temperature, high pressure geothermal water extracted from production well 202a. Production well 202a is drilled through rock formation 208 to a very high temperature geothermal fluid (SHGF) layer 210 that serves as a source of high temperature, high pressure geothermal water. The geothermal water is heated by convection in dry rock formation 212, which is heated by magma convection in magma reservoir 214. In FIG 2A, convection is represented by arrows, which indicate that hotter fluid rises to the upper part of each formation, cools and sinks, then rises again, repeating this ad infinitum.

[0030] As the geothermal water approaches the surface 207, the drop in temperature and pressure causes most of the geothermal water to rapidly turn to steam. Water changes phase from liquid to gas at 212° F. at 1400.7 psi (1 atm). However, at 250 psia, this phase change does not occur without a corresponding temperature of 400.97° F. Because geothermal water is a multi-phase fluid, i.e., it is not pure water, it flashes at various points along its path to the surface, creating water hammer and loud noise. Rock mufflers are commonly used as silencers, and chemicals are added for scale and corrosion control. When this complex mixture arrives at the phase separation unit, where some precipitation is likely to occur due to the pressure change, the steam is passed through a steam separator to separate the steam from the condensate, while the liquids and solids are sent to the injection well 204a. The steam is received by a turbine, which uses the steam's kinetic energy to generate rotational motion of a rotor within a stator to generate electricity, and the steam condenses into a liquid state for re-injection into the injection well 204a. This is a significant difference over fossil- and nuclear-fueled steam-operated plants, which recycle most of the steam by superheating. As a result, cooling towers for geothermal plants can be up to eight times larger than their comparable counterparts.

[0031] FIG. 2B illustrates a theoretical Very High Temperature Geothermal System (SHGS) power generation system. The SHGS power generation system 200b includes a production well 300 and an injection well 206b, each drilled from the surface 207 to the dry rock formation 212. Geothermal power generated from the SHGS power generation system 200b has been previously documented at various sites of the International Deep Drilling Project (IDDP). The Very High Temperature Geothermal Fluid (SHGF) utilized by the SHGS 200b is between 660-1472°F, but appears to flow convectingly under the direct influence of the underlying magmatic convection, unlike the convective heat that generates conventional geothermal water. This observation suggests that the SHGF in the dry rock formation 212 never runs out.

[0032] The challenges associated with extracting SHGF are the same as those for conventional geothermal flash plants, but at a larger level of scale. It is clear from the IDDP that improvements and innovations must be made to make this SHGF resource accessible and reliable, as discussed in more detail in Figure 3 below.

[0033] 2C illustrates a magma-based geothermal power generation system ("Magma System") according to an example embodiment. Magma System 200c includes a single well 600 extending from the surface 207 to the magma reservoir 214. Importantly, Magma System 200c is a closed system with no injection wells. Thus, unlike conventional geothermal system 200a and SHGS geothermal system 200b, respectively, Magma System 200c is free of the risk of thermal shock induced earthquakes that may result from the injection of cooling system water into a hot geothermal field.

[0034] One of the primary advantages of the magma system 200c is the simplicity of the design. Since only clean steam reaches the surface 207, no solid phase separation equipment is required. Only the separator is required to ensure that condensate does not reach the turbine. Additionally, since polybaric fluids do not reach the surface, there is no water hammer and no rock muffler is required. Another advantage of the magma system 200c is due to the energy density of the magma. A single well 600 can generate the power of multiple wells of a conventional geothermal plant. A detailed discussion of the well 600 is provided in conjunction with FIG. 6.

[0035] FIG. 3 is a cross-sectional view of a conventional well for use in the theoretical SHGS of FIG. 2B. The well 300 extends from the surface 207 to the dry rock formation 212. The well 300 includes a concrete-lined well casing 302 connected to a well screen 304 at the distal end of the well 300. The SHGF that enters the volume 304 defined by the well screen is conveyed to the surface 207 by a draw pipe 306. A pump 308 and motor 310 immersed in the SHGF and located at the end of the draw pipe 306 pump the SHGF to the surface 207. Conventional pumps for use in conventional oil and natural gas applications are rated at approximately 662° F. Immersing the pump 308 in SHGF, a corrosive fluid with temperatures roughly at the limit of the operating temperature of the pump 308, is likely to cause premature equipment failure. In fact, past attempts to utilize SHGF through the well 300 have failed in less than two years of operation.

[0036] The SHGF withdrawn from the well 300 may include solids, liquids, and / or gases, which may need to be passed through one or more separators as previously described.

[0037] FIG. 4A is a partial cross-sectional view of a well for use with the SHGS power generation system 200b of FIG. 2B according to an embodiment of the present disclosure. FIG. 4A shows the well with the slidable casing 408 in an elevated initial position while fluid enters the well 400 to be heated, while in this initial position, FIG. 4B shows the slidable casing 408 in a lowered final position such that heated fluid is propelled up the draw pipe 414 to the surface 207. In particular, the well 400 is intended to replace the conventional well 300 shown in FIG. 2B and FIG. 3. The well 400 utilizes a compressed air well pump, which has the advantage of eliminating the submerged motor and pump from the well 300 of FIG. 3.

[0038] Wellbore 400 extends from the earth's surface 207 to an underground reservoir of SHGF within dry rock formation 212. Wellbore 400 includes a concrete-lined well casing string 402 connected to a well screen 404 that is at least partially immersed in the underground reservoir. Well screen 404 defines a volume of the underground reservoir configured to be at least partially filled by the SHGF through a set of apertures 406.

[0039] The well 400 further comprises a slidable casing 408 having a first end 408a and a second end 408b. The slidable casing 408 defines an opening 410 at the first end 408a that opens into a cavity 412 bounded by a sidewall 408c and an end wall 408d at the second end 408b. Further, the slidable casing 408 is suspended within the well 400 and is coaxially aligned with the well screen 404.

[0040] The well 400 further comprises a draw pipe 414 extending through the end wall 408d of the slidable casing 408 and into the volume 404 defined by the well screen. The draw pipe 414 is configured to convey SHGF from the underground reservoir of SHGF to the surface 207 in response to the slidable casing 408 being slidably repositioned from an initial position to a final position such that the slidable casing 408 blocks more of the set of apertures 406 of the well screen 404, i.e., a larger portion of the slidable casing 408 is repositioned within the volume of the well screen 404, and an increase in pressure within the cavity 412 of the slidable casing 408.

[0041] By repositioning the slideable casing 408 to a final position occupying at least a larger volume within the well screen 404 (see FIG. 4B), the cavity 412 of the slideable casing 408 can be substantially filled with SHGF. The increased pressure within the cavity 412 forces the SHGF 412 within the cavity up the draw pipe 414 to the surface 207. The increased pressure can be maintained until the cavity 412 is substantially free of SHGF. By repositioning the slideable casing 408 to an initial position (see FIG. 4A), the volume 404 defined by the well screen can be refilled with SHGF so that the process can be repeated. Once the slideable casing 408 is repositioned to the initial position, the draw pipe 414 can be sealed to prevent unintended transfer of fluid between the draw pipe 414 and the volume 404 defined by the well screen. In one non-limiting embodiment, the draw pipe 414 is sealed by a valve 415 at or near the end of the draw pipe 414.

[0042] The slidable casing 408 can be repositioned from an initial position to a final position within the well 400 by a lift 416 coupled to an end wall 408d of the slidable casing 408. Non-limiting examples of the lift 416 can include a hydraulic ram or a winch attached to the slidable casing 408 by a set of steel cables. In embodiments where the lift 416 is a winch connected to the slidable casing 408 by a set of cables, the slidable casing 408 should be formed to have sufficient weight to allow the slidable casing 408 to advance deeper within the well 400 without the presence of any upward force.

[0043] Pressure can be increased within the cavity 412 of the slidable casing 408 by a supply of compressed air provided by a compressor 418 fluidly connected to the cavity 412 by an inlet pipe 420 extending through an end wall 408d of the slidable casing 408. The slidable casing 408 includes a set of adjustable apertures 500 that can be sealed around fluid conduits passing through the end wall 408d of the slidable casing 408, such as the inlet pipe 420 and the draw pipe 414, to enable pressure to be increased within the cavity 412. In an open configuration, the set of adjustable apertures 500 provide a clearance around the fluid conduits large enough to allow movement of the slidable casing 408 without any discernible obstruction.

[0044] In some embodiments, a check valve 422 may be positioned through an end wall 408d of the slidable casing 408 to help regulate the pressure within the cavity 412 of the slidable casing 408 in preparation for repositioning the slidable casing 408 and for pressurizing the cavity 412.

[0045] 5A-5C are various views of an adjustable aperture according to an exemplary embodiment. The adjustable aperture 500 is formed by disposing a collar seal 501 around an aperture 424 formed in an end wall 408d of the slidable casing 408 of FIGS. 4A and 4B to form the adjustable aperture 500. The collar seal 501 can be actuated to seal around a pipe passing through the aperture 424 in the end wall 408d, such as the draw pipe 414, thereby creating an airtight seal around the pipe. The airtight seal allows for pressurization of the cavity 412.

[0046] FIG. 5A is a cross-sectional view of a collar seal 501. A body 502 of the collar seal 501 has a generally toroidal shape and is secured to an upper surface of the end wall 408d of the slidable casing 408. In this FIG. 5A embodiment, the body 502 of the collar seal 501 is secured by a set of bolts. The body 502 may be formed from a rigid material such as steel. A gasket 504 may be disposed between the body 502 and the upper surface of the end wall 408d to form an airtight seal.

[0047] When actuated, the sealing connector 506 extends radially inward from the body 502 of the collar seal 501 until it engages the outer surface of the draw pipe 414. In one non-limiting embodiment, the collar seal 501 is pneumatically actuated by a source of compressed air (not shown) connected to an air valve 508 by a fluid conduit (not shown). The compressed air expands the sealing connector 506 to engage the draw pipe 414. In other embodiments, the collar seal 501 can be actuated by other means, such as electromechanical control. The sealing connector 506 in one exemplary embodiment is a pneumatic bladder. Releasing pressure from the sealing connector 506 allows the slidable casing 408 to move between the initial and final positions shown in FIGS. 4A and 4B. The expansion of the sealing connector 506 can prevent movement of the slidable casing 408 and / or prevent leakage of fluid from the slidable casing 408 as the fluid is pumped to the surface 207. For example, the sealing connector 506 can be expanded in the configuration of FIG. 4B and contracted in the configuration of FIG. 4A.

[0048] Figure 5B is a top view of collar seal 501 and Figure 5C is a bottom view of collar seal 501 according to an example embodiment. In Figure 5B, a number of bolts are circumferentially disposed around body 502. In Figure 5C, gasket 504 is shown disposed on a surface of body 502 that engages the top surface of slidable casing end wall 408d.

[0049] FIG. 6 is a cross-sectional view of a cased wellbore for use with the magma system of FIG. 2C according to an exemplary embodiment. The cased wellbore 600 is generally formed from a boiler casing 602 that passes through a well casing 604 and extends the entire length of the borehole from the surface 207 to the underground reservoir of magma 214. The boiler casing 602 houses a drill stem 1500 that is substantially coaxial with and coextensive with the boiler casing 602. The boiler casing 602 also houses a fluid conduit 800 configured to deliver a liquid-phase fluid into the boiler casing 602. In one embodiment, the liquid-phase fluid is water. The liquid-phase fluid, i.e., water, is converted to steam inside the boiler casing 602 and can be extracted as steam and later used to generate electricity by one or more turbines.

[0050] In one non-limiting embodiment, the well casing 604 extends only from the earth's surface 207 to a predetermined depth within the borehole. In the example shown in Figure 6, the well casing 604 extends from the earth's surface 207 to the interface between the dry rock layer 608 and the intrusive rock layer 610.

[0051] The boiler casing 602 has a first end 602a and a terminal end 602b that is immersed in the underground reservoir of magma 214. The boiler casing 602 may be coaxially aligned and sized relative to the well casing 604 such that the inner surface of the well casing 604 and the outer surface of the boiler casing 602 define an annular gap 612. An insulating layer 700 may be disposed within the annular gap 612 to insulate the boiler casing 602 for a predetermined length L measured from the first end 602a. Further details regarding the insulating layer 700 may be found in the discussion below with respect to FIG.

[0052] One end of the cased wellbore 600 is sealed by an end plate 614 with an aperture sized to receive the drill stem 1500. The end plate 614 prevents magma from entering the end 602b of the boiler casing 602. The other end of the cased wellbore 600 is sealed by a wellhead 1000, shown and described in more detail in FIG.

[0053] The magma in the underground reservoir is at a temperature between 1,600-2,300°F and is believed to be composed of numerous liquid metals such as Fe. End 602b of boiler casing 602 is immersed in the magma, causing boiler casing 602 to absorb heat from the magma. The heat is transferred to water provided by fluid conduit 800. Water enters the well through injection pipe 624, which may be the upper portion of fluid conduit 800 or a separate fluid pipe connected to fluid conduit 800. (In a closed system, pressure and temperature are related such that an increase in temperature causes an increase in pressure and vice versa. For example, the maximum possible temperature of saturated steam and water in the boiler casing 602 is 705.5°F at 3,208.2 psia, which is less than half the temperature of the magma in contact with the surface of the boiler casing 602.) As the water temperature increases, a predictable increase in pressure occurs, which forces the water to move up the boiler casing toward the surface 207. When the temperature and / or pressure decrease, the water is converted to steam that can be used to turn a set of turbines to generate electricity by methods previously described. The steam is removed from the well using a draw pipe 622.

[0054] As an added benefit, it is believed that heat loss from magma in contact with the boiler casing 602 results in the formation of a relatively thin, insulating, protective layer of intrusive rock on the boiler casing 602 that can retard corrosion.

[0055] 7A and 7B are various views of the first end, top end, of the cased well of FIG. 6 according to an exemplary embodiment. In particular, FIG. 7A is a partial view of the cased well 600 of FIG. 6, and FIG. 7B is a cross-sectional view of the cased well 600 taken along line 7B-7B of FIG. 7A. From FIG. 7A, it can be seen that a length L of the boiler casing 602 is insulated by an insulating layer 700 to reduce heat loss at the top end of the boiler casing 602, thereby preventing the steam from being converted back into condensate.

[0056] Figures 8A and 8B are various views of the fluid injection conduit of the cased well of Figure 6 according to an example embodiment. Figure 8A is a cross-sectional view of the fluid conduit 800 taken along line 8A-8A of Figure 6, and Figure 8B is a cross-sectional view of the fluid conduit 800 taken along line 8B-8B of Figure 6.

[0057] The fluid injection conduit 800 is a laminated fluid conduit insulated from the high heat and pressure inside the boiler casing 602 to prevent liquid phase fluid, i.e., water, from reaching the end 602b of the boiler casing 602 after flashing to gas phase fluid, i.e., steam. The exemplary fluid injection conduit 800 of FIG. 8 is formed from a fluid conduit 802 encased in an inner insulating layer 804, which is encased in an outer insulating casing layer 806. In one non-limiting embodiment, the outer insulating casing layer 806 is formed from a rigid material to protect against high pressure, and the inner casing layer 804 provides thermal insulation properties.

[0058] Figures 9A and 9B are various views of the second end, terminus, of the cased well of Figure 6 according to an example embodiment. Figure 9A is a more detailed view of a cross section of the boiler casing 602 of Figure 6, and Figure 9B is a cross section of the boiler casing 602 taken along line 9B-9B of Figure 9A.

[0059] The boiler casing 602 may be formed from a number of boiler casing segments 602c welded end-to-end at seams 616. In one non-limiting embodiment, the interior volume of the boiler casing 602 is divided into a number of compartments 602d by a set of casing plates 618. Each of the set of casing plates 618 includes a number of apertures 620 connecting each compartment 602d with one or more adjacent compartments 602d. A first aperture 620b of the number of apertures 620 is sized to accommodate the fluid conduit 800. A second aperture 620a is sized to receive the drill stem 1500. In one non-limiting embodiment, the outer surface of the drill stem 1500 is welded to each of the set of casing plates along the periphery of the second aperture 620b. The remaining apertures 620c are steam vents that allow for transport through the multiple sections 602d towards the surface 207.

[0060] 10A-10C are various views of the wellhead of the cased well of FIG. 6 in accordance with an exemplary embodiment. In particular, FIG. 10A is a partial cutaway view of the wellhead 1000, FIG. 10B is a top view of the wellhead 1000, and FIG. 10C is an elevation view of the wellhead 1000. The wellhead includes a drill stem cap 1100 that prevents pressure build-up within the wellbore that may rupture fluid conduits such as the draw pipe 622. The drill stem cap 1100 can include, but is not limited to, a vent cap.

[0061] The wellhead 1000 comprises a first mating surface 1002 configured to mate with the first end 602a of the boiler casing 602. In one non-limiting embodiment, the first mating surface 1002 is a flange configured to be bolted to a corresponding flange of the boiler casing 602. The wellhead 1000 further comprises another mating surface 1004, e.g., another flange, configured to mate with the draw pipe 622 and a steam valve 1006 that can isolate the casing wellbore 600 from any downstream unit operations. Additionally, the wellhead 1000 depicted in FIG. 10 comprises a number of apertures that allow the fluid conduit 800 and the drill stem 1500 to be exposed above the earth's surface 207.

[0062] 11A-11C show various views of a vent cap for use with the cased well of FIG. 6 according to an exemplary embodiment. The drill stem cap 1100 is configured to removably engage the upper end of the drill stem 1500 to protect the threaded connection and provide a means for regulating pressure within the drill stem 1500.

[0063] 11A is a side view of a drill stem cap 1100 having a vent 1102 that can relieve pressure build-up within the drill stem 1500. The elevated pressure can be due to magma seeping into the drill stem 1500 from around a sacrificial bit attached to the end of the drill stem 1500 after the sacrificial bit is immersed in magma.

[0064] FIG 11B is a bottom view of the drill stem cap 1100 looking up into the cavity 1104 of the drill stem cap 1100 and showing the threaded receiver 1106 connecting to the vent 1102. FIG 11C is a cross-sectional view of the vent 1102 taken along line 11C-11C of FIG 11A. The threaded connector 1108 of the vent 1102 can be inserted into the threaded receiver 1106 of the drill stem cap 1100 to removably connect the two. The threaded connector 1108 defines a conduit connecting the cavity 1104 of the drill stem cap 1100 with the set of outlets 1110 described above to prevent pressurization of the drill stem 1500.

[0065] 12 is a simplified schematic diagram of a magma power system according to an example embodiment. The magma power system 1200 includes a steam separator 1202 directly connected to a cased well 600 extending between the earth's surface and an underground reservoir of magma. The steam separator 1202 separates the vapor phase fluid, i.e., steam, from a condensate formed from the vapor phase fluid. A first set of turbines 1300 is connected to the steam separator and configured to generate electricity from the vapor phase fluid received from the steam separator 1202. A condensate tank 1204 is fluidly connected to the steam separator 1202 and the first set of turbines 1300. The condensate tank 1204 is fluidly connected to a fluid conduit that supplies the condensate to the cased well 600.

[0066] Given that the temperature and pressure of the steam generated from the casing wells 600 is sufficiently high, a second set of steam turbines 1300' may be placed in series with the first set of steam turbines 1300 to generate electricity from the steam exhausted from the first set of steam turbines 1300. Condensate obtained from the second set of steam turbines 1300' may also be sent to the condensate tank 1204. As used herein, the first set of steam turbines 1300 may also be referred to as the "high pressure turbine" and the second set of turbines 1300' may also be referred to as the "low pressure turbine" that operates at a lower pressure than the first set of steam turbines 1300.

[0067] In some embodiments, exhaust from at least the second set of steam turbines 1300′ and optionally the first set of steam turbines 1300 may be sent to a set of exhaust recyclers 1206. Examples of exhaust recyclers 1206 include, but are not limited to, one or more of a water distillation system 1206a, a thermally driven chiller 1206b, a residential HVAC system 1206c, an agricultural system 1206d, and an aquaculture system 1206e. The exhaust generated by the exhaust recycler 1206 may be sent to a cooling tower 1208, if desired, before being returned to the condensate tank 1204 for use in resupplying the wells 600.

[0068] The heat-driven chillers 1206b can be implemented in data centers, cryptocurrency mining facilities, or other locations where undesirable amounts of heat are generated. Heat-driven chillers 1206b, also known as conventional absorption cooling systems, use heat to generate chilled water. These heat-driven chillers 1206b can be designed as direct-fired units, indirect-fired units, and heat recovery units. Indirect-fired units are preferred when the exhaust includes low-pressure steam.

[0069] The thermally driven chiller 1206b features a simple design with few moving parts resulting in low maintenance requirements, low operating temperatures and pressures, e.g., 200-370°F and 10-115 psig), low power consumption, e.g., 0.01-0.04 KW / ton, high heat release rates, e.g., 21,000 BTU / ton-h to 30,000 BTU / ton-h (11 refrigeration tons = 12,000 BTU), large physical size and weight, e.g., 1,000 tons of refrigerant = 65,000-74,000 lbs and 20 ft L x 8 ft W x 12 ft H, and the use of ozone-safe, low global warming potential refrigerants.

[0070] At least one advantage of the Magma Power System 1200 over the prior art is increased efficiency. This can be attributed to a simpler plant design with fewer parasitic loads such as pumps, and a better heat source than conventional geothermal systems, which increases usable energy to entropy. Another advantage of the Magma Power System 1200 is the implementation of an exhaust recycler 1206 that can convert much of the remaining steam into condensate without the need to route the steam through a cooling tower 1208.

[0071] 13 is a diagram of a set of turbines for use in a Magma power system according to an example embodiment. The steam turbine set 1300 is one or more turbines 1302 connected to a steam distribution manifold 1304. Each of the turbines in the set 1302 is a high pressure steam turbine capable of generating electrical power from steam received from the steam distribution manifold 1304, given that the received steam has a sufficiently high temperature and pressure.

[0072] 13 embodiment, steam received by steam manifold 1304 originates from casing wells 600. Condensate formed during operation of the set of turbines 300 may be returned to casing wells 600.

[0073] 14A and 14B are various views of a drill bit for use in drilling a well for a magma system according to an exemplary embodiment. The drill bit 1400 may be attached to a drill stem for drilling a well, such as the well 600 of FIG. 4. With particular reference to FIG. 14A, the drill bit 1400 is shown as a tricone drill bit having an integral underreamer 1402 that projects radially outward. A discharge nozzle 1404 is positioned to supply drilling fluid to a working connection of the drill bit 1400 during drilling operations.

[0074] The underreamer 1402 engages the end of the well casing 602 so that the well casing can be carried into the borehole as the drill bit 1400 drills downward. As used herein, the terms "up," "down," "upward," "downward," and other similar terms are relative to the gravity vector. Thus, drilling from the earth's surface toward an underground reservoir of fluid is in a downward direction. The underreamer 1402 can be withdrawn or retracted to allow for withdrawal of the drill bit 1400 from the borehole without simultaneously withdrawing the well casing.

[0075] FIG. 14B is a top view of the drill bit 1400 showing the hollow center of the attachment connector, which allows drilling fluid conveyed down the drill stem to flow through a discharge nozzle 1404 to cool the drill bit 1400 and push cuttings out of the wellbore.

[0076] The drill bit 1400 shown in Figure 14 is exemplary and non-limiting. For example, although the under-reamer 1402 is shown as being integral with the drill bit 1400 in Figure 14, in alternative embodiments, the under-reamer 1402 may be formed to be a drill stem attached to the drill bit 1400. Additionally, although the drill bit 1400 is shown as a tricone bit, other drill bit configurations now used or developed in the future may be used instead.

[0077] 15A and 15B are various views of a drill stem for use in drilling a well for a magma system according to an example embodiment. The drill stem 1500 can be coupled to a drill bit, such as the drill bit 1400, for drilling the well.

[0078] FIG 15A is an elevational view of a drill stem 1500 and FIG 15B is a cross-sectional view of the drill stem 1500 of FIG 15A taken along line 15B-15B. The drill stem 1500 has a hollow center for conveying drilling fluid down a borehole during drilling operations. The drill stem 1500 includes an attachment connector at an upper end that is configured to receive a drill stem cap once drilling operations are completed. An example of a drill stem cap is depicted in FIG 11.

[0079] FIG. 16 is a system for generating superheated steam according to an exemplary embodiment. The superheated steam system 1600 can be used to generate superheated steam that can be used for various applications such as Fischer-Tropsch synthesis (FTS) and the Haber process. FTS can be used to generate synthetic hydrocarbons, and the Haber process can be used to produce ammonia. Both processes require a source of steam with a higher temperature and pressure than saturated steam. The superheated steam can be generated using one or more wells. In a preferred embodiment, the system is configured with two or more wells as shown in the example of FIG. 16. The use of two or more wells can facilitate simpler operations and the use of less costly materials.

[0080] Saturated steam is a two-phase mixture of liquid and gas. When water is contained in a pressure vessel and heated, the temperature and pressure rise together in a predictable relationship. These pressure, temperature, volume, and energy relationships are well known to engineers and are published in steam tables. In a pressurized system, saturated steam is constantly losing energy to the environment, increasing in entropy, which manifests itself as condensate that forms on the inside of the pipe walls and collects at the bottom of the pipe or vessel in the direction of gravity. In saturated steam plants, such as canneries and commercial laundries, all steam pipes are tilted at an angle to the earth, and steam traps collect the liquid water and return it to steam production while the steam in the system continues to do work.

[0081] By capturing steam and passing it through a heat exchanger to reheat it, the steam has more energy (enthalpy) than is associated with the pressure and volume of the steam and cannot evaporate. This reheated steam is called superheated steam. Superheated steam is not a two-phase mixture and exists only as a gas. This is preferred by operators of Rankine cycle power plants because any condensate droplets from saturated steam can damage turbine blades.

[0082] When saturated steam reaches 3,208.2 psi (22.089 MPa) and 705.5°F (647.29 K), the volume required in cubic feed per pound of steam is zero, the potential for evaporation is zero, and the energy content of the liquid and gas phases of water are identical. In other words, water turns to steam without boiling, and the two aforementioned states become indistinguishable. This is called the critical point.

[0083] The FTS and Haber processes require pressures in excess of 2900 psi and temperatures in excess of 800° F. The pressures are within the saturation range, but the temperatures are not. These processes require superheated steam, which can be obtained by the superheated steam system 1600.

[0084] The superheated steam system 1600 includes a casing well 1700, described in more detail in FIG. 17 below, for generating superheated steam from saturated steam received from a casing well 600, described in more detail in FIG. 6 above.

[0085] The water injected into well 600 may be withdrawn as saturated steam having a temperature of about 650° F. The saturated steam may then be injected into downstream well 1700, which may then be withdrawn as superheated steam at a temperature of about 900° F. As previously described, the superheated steam may then be processed in plant 1602 to generate electricity, synthetic fuels, or ammonia.

[0086] 17A-17C are various views of a wellbore for generating superheated steam according to an example embodiment. In particular, FIG. 17A is a cross-sectional view of wellbore 1700, FIG. 17B is a cross-sectional view of wellbore 1700 taken along line 17B-17B of FIG. 17A, and FIG. 17C is a plan view of the top of wellbore 1700.

[0087] The casing well 1700 has a first end 1700a at the earth's surface 207 and a second end 1700b at the underground reservoir of magma 214. The casing well 1700 further comprises a fluid passageway 1702 (represented by arrow 1702a) extending from an inlet 1704 at the first end 1700a to the second end 1700b and then from the second end 1700b to an outlet 1706 at the first end 1700a. The fluid passageway 1702 is configured to receive a heat transfer fluid at the inlet 1704 and to discharge superheated steam at the outlet 1706. An example of a heat transfer fluid includes, but is not limited to, saturated water steam. The saturated steam is converted to superheated steam in the fluid passageway 1702 at the second end 1700b of the casing well 1700. Diameter 1722 of the inlet fluid passage 1702 conduit has a value of "a" and diameter 1720 of the outlet conduit has a value of "b," which may be the same or different, i.e., a=b or ≠ b. In one or more embodiments of the present disclosure, diameter 1722 (e.g., corresponding to the volume of the inner casing of the wellbore 1700) is greater than diameter 1720 (e.g., corresponding to the volume of the annulus between the inner casing and the wall of the wellbore 1700). This difference in diameters and the corresponding difference in volumes creates a pressure drop that helps move the steam flow to the surface 207.

[0088] In one non-limiting embodiment, the well 1700 has a well casing 1708 extending from the surface 207 toward the underground reservoir 214 of magma, and the fluid passageway 1702 is formed from a set of boiler casings 1708 extending through the well casing. The set of boiler casings can include a first boiler casing 1710 defining a first fluid conduit configured to convey saturated steam from a first end 1700a of the casing well 1700 to a second end 1700b of the casing well 1700. The set of boiler casings can further include a second boiler casing 1712 defining a second fluid conduit configured to convey superheated steam from the second end 1700b of the casing well 1700 to the first end 1700a of the casing well 1700.

[0089] In a particular embodiment, the first boiler casing 1710 has a first cross-sectional area and the second boiler casing 1712 has a second cross-sectional area that is smaller than the first cross-sectional area. The second boiler casing 1712 can be substantially coextensively received within the first boiler casing 1710 to form an elongated annular volume space 1714 between an inner surface of a sidewall of the first boiler casing 1710 and an outer surface of a sidewall of the second boiler casing 1712. In this embodiment, the first fluid conduit is the elongated annular volume space 1714 and the second fluid conduit is an elongated volume space bounded by the sidewall of the second boiler casing 1712.

[0090] In another particular embodiment, the first boiler casing 1710 has a first cross-sectional area and the second boiler casing 1712 has a second cross-sectional area that is greater than the first cross-sectional area. The first boiler casing 1710 can be substantially coextensively received within the second boiler casing 1712 to define an elongated annular volume 1714 between an inner surface of a sidewall of the second boiler casing 1712 and an outer surface of a sidewall of the first boiler casing 1710. In this embodiment, the first fluid conduit is the elongated annular volume 1714 and the second fluid conduit is the elongated volume 1714 bounded by the sidewall of the first boiler casing 1710.

[0091] The upper end of the casing well 1700 may be sealed by a wellhead 1716. The wellhead 1716 may include a first connector 1716a configured to fluidly connect the inlet 1704 of the fluid passage to a source of saturated steam, such as the casing well 600 of FIG. 16, and a second connector 1716b configured to fluidly connect the outlet 1706 of the fluid passage to a system for generating power from superheated steam.

[0092] In one non-limiting embodiment, as seen in FIG. 17B, the sidewall of the inner boiler casing 1712 is corrugated to increase heat transfer at the end closest to the second end 1700b of the casing well 1700. In this non-limiting embodiment, the sidewall of the inner boiler casing is not corrugated at the end closest to the first end 1700a of the casing well 1700. To further prevent heat transfer at the first end 1700a of the casing well 1700, an insulating layer 1718 may be disposed around the outer boiler casing 1710 at the first end 1700a.

[0093] FIG 18 is a cross-sectional view of a boiler casing for use in the downstream well of FIG 17A, and FIGs 19A and 19B are various views of another boiler casing for use in the downstream well of FIG 17A according to an exemplary embodiment. The boiler casing 1800 has a smooth surface and a cross-sectional area based on dimension D1. The boiler casing 1800 can encase a corrugated boiler casing 1900 shown in FIGs 19A and 19B, which has a cross-sectional area based on dimension D2, where D1 is greater than D2. The corrugated surface of the boiler casing 1900 increases the surface area for heat transfer.

[0094] The rate of heat transfer through a material due to a change in temperature in one-dimensional conduction can be expressed by Fourier's law:

number

[0095] The minus sign in the equation indicates that the heat flow is in the direction of decreasing temperature. However, given that an intrusive rock layer is likely to form on the face of the outer conductor casing soon after installation, two heat transfer gradients must be considered: one through the intrusive rock and one through the metal casing.

[0096] 20 is a flow diagram of a method for pumping very high temperature geothermal fluid (SHGF) through a cased well bore according to an example embodiment. Flow diagram 2000 may be implemented in cased well bore 400 of FIG. 4 that extends from the Earth's surface to an underground reservoir of magma.

[0097] Flowchart 2000 begins in step 2002 by repositioning a slideable casing from an initial position within the borehole between the surface and the underground reservoir to a final position at least partially within the underground reservoir. In one non-limiting embodiment, the slideable casing has an opening at a first end that opens into a cavity bounded by a sidewall and an end wall at a second end, the slideable casing is coaxially aligned with a well screen at the end of the casing string and is at least partially immersed in the underground reservoir. Additionally, the well casing includes a set of apertures that allow the inflow of SHGF into a volume defined by the well screen. In the final position, the cavity of the slideable casing substantially coincides with the volume defined by the well screen to prevent flow of SHGF through the set of apertures, and the cavity is filled with SHGF from the volume defined by the well screen.

[0098] In step 2004, the slidable casing is secured in a final position within the borehole. Securing the slidable casing may include sealing the cavity by actuation of a set of adjustable apertures. In an embodiment in which the set of adjustable apertures are one or more pneumatically actuated pipe collar seals, sealing the cavity may include sealing one or more pneumatically actuated pipe collar seals surrounding a fluid conduit passing through the set of adjustable apertures.

[0099] In step 2006, pressure is increased within the cavity of the slidable casing to cause the SHGF within the cavity to flow into a draw pipe that extends through an end wall of the slidable casing and into the cavity. The pressure within the cavity may be increased by providing a compressed fluid within the cavity of the slidable casing. In one embodiment where the compressed fluid is compressed air, the compressed air may be provided by conveying compressed air through an inlet pipe that passes through the cavity in the end wall of the slidable casing. Additionally, conveying compressed air through the inlet pipe may include the further step of closing a pressure control valve located within the end wall of the slidable casing.

[0100] In step 2008, the SHGF is transported to the surface through a draw pipe.

[0101] In step 2010, the slidable casing is repositioned from the final position to the initial position in response to the cavity being substantially empty of SHGF. In one non-limiting embodiment, the slidable casing is repositioned from the final position to the initial position before sliding the slidable casing after reducing the pressure in the cavity of the slidable casing. The pressure can be reduced by opening a pressure control valve and / or expanding one of a set of adjustable apertures disposed in an end wall of the slidable casing.

[0102] The volume defined by the well screen is then allowed to be filled with SHGF in step 2012. Once filled, the flow chart 2000 returns to step 2002 which allows another aliquot of SHGF to be delivered to the surface.

[0103] In flow diagram 2000, repositioning the slidable casing may be accomplished by activating a water ram and / or a winch coupled to the slidable casing.

[0104] 21 is a flowchart of a method for generating power with a magma system according to an example embodiment. The steps of flowchart 2100 may be performed in a geothermal power plant, such as geothermal power plant 200c of FIG. 2C.

[0105] Flow diagram 2100 begins in step 2102 by supplying a liquid-phase fluid to a cased wellbore that extends from the earth's surface to an underground reservoir of magma. Heat supplied from the magma causes the liquid-phase fluid to change to a gas-phase fluid that is transported up the cased wellbore to the earth's surface.

[0106] In step 2104, the gas-phase fluid is separated from the condensate formed from the gas-phase fluid.

[0107] In step 2106, the set of turbines are operated with the gas phase fluid to generate electricity. In an embodiment where the set of turbines comprises at least two turbines arranged in series, step 2106 may include the further steps of operating an upstream turbine with the gas phase fluid at a first pressure, then operating a downstream turbine with the gas phase fluid received from the upstream turbine, and then accumulating at least some condensate from the upstream turbine and the downstream turbine for supply to the casing well. The downstream turbine may be operated at a second pressure lower than the first pressure.

[0108] In step 2108, at least a portion of the condensate formed from the vapor-phase fluid is accumulated.

[0109] In step 2110, the accumulated condensate is delivered to the casing well as a liquid phase fluid.

[0110] The exhaust from the set of turbines may still have enough heat and pressure to power further equipment. Thus, flow chart 2100 may include an optional step 2112a of conveying the exhaust from the set of turbines to a set of thermally driven chillers configured to perform air conditioning. The set of thermally driven chillers may be used to cool computing equipment such as a server room or a bitcoin mining operation.

[0111] Flowchart 2100 may further include an optional step 2112b of conveying exhaust from the set of turbines to an exhaust recycler comprising one or more of a water distillation system, a thermally powered cooling system, a residential heating system, an agricultural system, and an aquaculture system.

[0112] 22 is a flow chart of a method for forming a cased well bore according to an example embodiment. The steps of flow chart 2200 may be performed to form cased well bore 600 of FIG. 6 that extends from the earth's surface to an underground reservoir of magma.

[0113] Flowchart 2200 begins by drilling a well from the earth's surface towards an underground reservoir of magma in step 2202. The well may be drilled from the earth's surface to a target depth.

[0114] In step 2204, the well casing is suspended within the wellbore. In one non-limiting embodiment, the wellbore is drilled from the surface toward an underground reservoir of magma with a drill bit disposed at the end of a drill stem that is continuously extended as the drill bit advances toward the underground reservoir. In this non-limiting embodiment, the well casing is coupled to an underreamer positioned at a terminal region of the drill stem such that the well casing is extended as the drill stem is extended. Thus, suspending the well casing may include conveying the well casing into the wellbore while advancing the drill bit toward the underground reservoir.

[0115] In step 2206, the boiler casing is suspended within the well casing in response to the well reaching the target depth.

[0116] Drilling of the well is resumed to extend the well from the target depth to a final depth within the underground reservoir of magma at 2208. The boiler casing is extended from the surface to a final depth within the underground reservoir to form a cased well.

[0117] 23 is a flow diagram of a method for suspending a boiler casing according to an example embodiment. The steps of flow diagram 2300 may be performed at step 2206 of flow diagram 2200.

[0118] Flowchart 2300 begins in step 2302 with retracting the underreamer to release the well casing.

[0119] In step 2304, the drill stem and the first drill bit attached to the end of the drill stem are withdrawn.

[0120] In step 2306, the boiler casing is inserted into the well casing contained within the well.

[0121] 24 is a flow diagram of a method for inserting a boiler casing into a well casing contained within a well bore according to an example embodiment. The steps of flow diagram 2400 may be performed in step 2306 of flow diagram 2300.

[0122] In step 2402, the boiler casing may be inserted into the well casing by sealing the ends of the boiler casing with end plates having apertures sized to receive the drill stems.

[0123] In step 2404, the drill stem is welded to an end plate that surrounds the periphery of the aperture.

[0124] In step 2406, a sacrificial bit is coupled to the drill stem.

[0125] In step 2408, the end of the boiler casing is conveyed into the well casing.

[0126] 25 is a flow diagram of a method for transporting a boiler casing into a wellbore through a well casing according to an example embodiment. The steps of flow diagram 2500 may be performed at step 2408 of flow diagram 2400.

[0127] Flowchart 2500 begins in step 2502 by extending the drill stem and boiler casing as the end of the boiler casing is delivered into the well casing. The drill stem and boiler casing are extended from an end of the boiler opposite the end of the boiler casing.

[0128] In step 2504, the drill stem and boiler casing can be extended by fastening a pair of casing plates to the side walls of the boiler casing, and in step 2506, the outer surface of the drill stem is welded to each of the pair of casing plates surrounding a periphery of an aperture sized to receive the drill stem.

[0129] In step 2508, the boiler casing may be stretched by aligning a new boiler casing segment against the end of the boiler casing and then in step 2510, welding the new boiler casing segment to the end of the boiler casing.

[0130] In step 2512, the boiler casing is extended by drilling with a sacrificial bit from the target depth to a final depth until the sacrificial bit is immersed in the underground reservoir of magma at the final depth. Water and air pressure from the sacrificial bit causes the magma to cool quickly and turn to a solid-like state, and the sacrificial bit can cut through the solid phase and sweep it out to the annular gap for extraction at the surface.

[0131] In step 2514, liquid phase fluid is injected into the end of the boiler casing when the end of the boiler casing approaches the final depth.

[0132] 26 is a flow diagram of a method for generating superheated steam according to an example embodiment. The steps of flow diagram 2300 may be performed in a system for generating superheated steam, such as steam system 1600 of FIG.

[0133] Flow diagram 2600 begins in step 2602 with receiving saturated steam from a steam source. The steam source may be an upstream wellbore, such as wellbore 600 in Figure 6, that extends from the earth's surface to an underground reservoir of magma or another underground reservoir of magma.

[0134] In step 2604, the saturated steam is conveyed into a casing wellbore extending from the earth's surface to an underground reservoir of magma, exposing the saturated steam to heat from the underground reservoir of magma. The heat from the underground reservoir of magma converts the saturated steam to superheated steam. In one non-limiting embodiment, the saturated steam is conveyed through an annular volume between an outer boiler casing and an inner boiler casing housed within the outer boiler casing. In this non-limiting embodiment, the outer boiler casing is at least partially exposed to the magma in the underground reservoir, and a portion of the sidewall of the inner boiler casing is non-corrugated at an end closest to the underground reservoir of magma, and another portion of the sidewall of the inner boiler casing is non-corrugated at an end closest to the earth's surface.

[0135] In step 2606, the superheated steam is conveyed back towards the surface.

[0136] In optional step 2608, the superheated steam is provided to a set of turbines to generate electricity.

[0137] 27A-27C are various views of a wellbore for generating superheated steam according to another exemplary embodiment. In particular, FIG. 27A is a cross-sectional view of wellbore 2700, FIG. 27B is a cross-sectional view of wellbore 2700A of FIG. 27 taken along line 27B-27B, and FIG. 27C is a plan view of the top, or wellhead, of wellbore 2700.

[0138] The casing well 2700 has a first end 2700a at the earth's surface 207 and a second end 2700b at the underground reservoir of magma 214. The casing well 2700 further comprises a fluid passageway 2702 (represented by arrow 2702a) extending from an inlet 2704 at the first end 2700a to the second end 2700b and then from the second end 2700b to an outlet 2706 at the first end 2700a. The fluid passageway 2702 is configured to receive saturated steam at the inlet 2704 and to discharge superheated steam at the outlet 2706. The saturated steam is converted to superheated steam in the fluid passageway 2702 at the second end 2700b of the casing well 2700.

[0139] In one or more embodiments of the present disclosure, diameter 2720 (e.g., corresponding to the volume of the outlet of the outlet fluid conduit) is greater than diameter 2722 (e.g., corresponding to the volume of the annulus between the casing and the wall of wellbore 2700). This difference in diameters and the corresponding difference in volume creates a pressure drop that helps drive the flow of steam through wellbore 2700.

[0140] In one non-limiting embodiment, the well 2700 has a well casing 2708 extending from the earth's surface 207 toward the underground reservoir of magma 214, and the fluid passageway 2702 is formed from a set of boiler casings 2708 extending through the well casing. The set of boiler casings can include a first boiler casing 2710 defining a first fluid conduit configured to convey saturated steam from a first end 2700a of the casing well 2700 to a second end 2700b of the casing well 2700. The set of boiler casings can further include a second boiler casing 2712 defining a second fluid conduit configured to convey superheated steam from the second end 2700b of the casing well 2700 to the first end 2700a of the casing well 2700.

[0141] In a particular embodiment, the first boiler casing 2710 has a first cross-sectional area and the second boiler casing 2712 has a second cross-sectional area that is smaller than the first cross-sectional area. The second boiler casing 2712 can be substantially coextensively received within the first boiler casing 2710 to form an elongated annular volume 2714 between an inner surface of a sidewall of the first boiler casing 2710 and an outer surface of a sidewall of the second boiler casing 2712. In this embodiment, the first fluid conduit is the elongated annular volume 2714 and the second fluid conduit is an elongated volume bounded by the sidewall 2712 of the second boiler casing.

[0142] In another particular embodiment, the first boiler casing 2710 has a first cross-sectional area and the second boiler casing 2712 has a second cross-sectional area that is greater than the first cross-sectional area. The first boiler casing 2710 can be substantially coextensively received within the second boiler casing 2712 to form an elongated annular volume 2714 between an inner surface of a sidewall of the second boiler casing 2712 and an outer surface of a sidewall of the first boiler casing 2710. In this embodiment, the first fluid conduit is the elongated annular volume 2714 and the second fluid conduit is the elongated volume 2714 bounded by the sidewall of the first boiler casing 2710.

[0143] The upper end of the case well 2700 may be sealed by a wellhead 2716. The wellhead 2716 may include a first connector 2716a configured to connect the wellhead 2716 to an opposite connector of the well 2700. The wellhead 2716 may receive saturated steam from a case well, such as well 600 in FIG. 16, and provide superheated steam to a system for generating power from the superheated steam, such as plant 1602 in FIG. 16.

[0144] In one non-limiting embodiment, the sidewalls of the outer boiler casing 2712 are corrugated at the end closest to the second end 2700b of the casing well 2700 to increase heat transfer from the magma. In this non-limiting embodiment, the sidewalls of the outer boiler casing 2712 are not corrugated at the end closest to the first end 2700a of the casing well 2700. The sidewalls of the inner boiler casing 2710 are not corrugated along the entire length of the well 2700. To further prevent heat transfer at the first end 2700a of the casing well 2700, an insulating layer 2718 can be disposed around the outer boiler casing 2710 at the first end 2700a.

[0145] A set of casing plates can provide structural rigidity to the well 2700. In this exemplary embodiment, the well 2700 includes at least two casing plates 3000, shown in more detail in FIG. 30 and FIG. 3300, but can also include more than two casing plates 3000 disposed along the entire length of the well 2700. For example, the casing plates 3000 and / or 3300 can be installed at predetermined intervals to provide the necessary support and / or rigidity, for example, to every connector between boiler casing segments, to every other connector between boiler casing segments, or at some other interval.

[0146] The cross-sectional view of FIG. 27B shows a plan view of the casing plate 3300 as seen in the cross-sectional view of the wellbore 2700 taken along line 27B-27B of FIG. 27A. The casing plate 3300 has eight arms 3302 extending radially outward from a central body 3304. In this exemplary embodiment, the central body 3304 has a generally conical form defining a tubular bore configured to receive the drill stem 1500 that drives the sacrificial bit 1400. The arms 3302 of the casing plate 3300 connect the inner boiler casing 2710 and the outer boiler casing 2712 to provide support and / or rigidity. As shown in more detail in FIG. 32, the casing plate 3300 may be welded to the inner boiler casing 2710 and the outer boiler casing 2712.

[0147] 28A-28C are various views of the boiler casings of a well 2700 according to an example embodiment. FIG. 28A shows a cross-sectional view of the pair of boiler casings in the upper portion of the well 2700. The cross-sectional view is taken along line 28A-28A in FIG. 27. As can be seen, the arrangement of the first boiler casing 2710 and the second boiler casing 2712 forms a fluid passage for superheated steam with a circular cross-section and a fluid passage for saturated steam with an annular cross-section. The sidewalls of the first boiler casing 2710 and the second boiler casing 2712 are smooth.

[0148] FIG. 28B is a cross-sectional view of the pair of boiler casings used in the lower portion of well 2700. The cross-sectional view is taken along line 28B-28B in FIG. 27. The arrangement of first boiler casing 2710 and second boiler casing 2712 forms a fluid passage for superheated steam having a circular cross-section and a fluid passage for saturated steam having a generally annular cross-section. The sidewall of first boiler casing 2710 is smooth and the sidewall of second boiler casing 2712 is corrugated. FIG. 28C shows an elevation view of the boiler casings shown in FIG. 28B.

[0149] The boiler casing of the well 2700 may be formed from standard carbon steel and may be provided in 20' or 40' lengths, different diameters and different thicknesses. The boiler casing segments may be secured together by threaded connectors or welded joints. The corrugated section of the second boiler casing 2712 increases the area for heat exchange by up to about 57%. The corrugated boiler casing at the lower end of the well 2700 increases the rate of heat exchange from the magma reservoir so that saturated steam can be converted to superheated steam. The superheated steam can be conveyed upward through the portion of the fluid passageway in the first boiler casing 2710 and returned to the surface.

[0150] Figures 29 and 30 show different views of a casing plate installed in an upper portion of a wellbore in accordance with an exemplary embodiment. In particular, Figure 29 shows a more detailed view of casing plate 3000 installed in the upper portion of wellbore 2700 shown in Figure 27, and Figure 30 shows a plan view of casing plate 3000 taken from line 30-30 of Figure 29.

[0151] The exemplary casing plate 3000 has four arms 3002 extending from a central body region 3004. The central body region 3004 includes a hole configured to receive the drill stem 1500. The arms 3002 connect the first boiler casing 2710 with the second boiler casing 2712. The casing plate 3000 can be secured within the wellbore 2700 by conventional means, such as welding. Exemplary welds 2902 are identified in FIG.

[0152] The shape of the arms 3002 of the casing plate 3000 provides the necessary strength without impeding the passage of the fluid passages 2702. For example, each arm 3002 has a radial length extending from the central body region 3004 to the second boiler casing 2712. The casing plate 3000 secures the drill stem 1500 by the first boiler casing 2710 and the second boiler casing 2712. As can be seen in FIG. 31, which is a cross-sectional view taken along line 31-31 of FIG. 29, a portion of each arm 3002 can have a generally pentagonal shape. The leading edge 3006 of each arm 3002 is shaped to reduce the amount of resistance to the flow of fluid past each arm 3002 with superheated steam. In this exemplary embodiment, the cross-sectional size of the arms 3002 increases as the arms advance from the inner boiler casing 2710 toward the drill stem 1500, increasing the surface area of ​​the weld 2902 along the drill stem 1500. Similarly, each arm 3002 terminates in a flared tip 3008 that increases the surface area of ​​the weld 2902 to the second boiler casing 2712.

[0153] FIG. 32 is a cross-sectional view of an arm of a casing plate installed between two segments of a boiler casing according to an exemplary embodiment. In particular, the view is taken along line 32-32 of the well 2700 of FIG. 27 and shows the arm 3002 passing through the first boiler casing 2710. The first boiler casing 2710 is formed from a number of boiler casing segments, two of which are shown in FIG. 32 as boiler casing segments 2710a and 2710b. Placing the casing plate 3000 at the connector between two consecutive boiler casing segments reduces the number of separate welding steps that need to be performed to assemble the well 2700, since the boiler casing segments 2710a and 2710b will be welded anyway. In this exemplary embodiment, welds 2902 are located between boiler casing segments 2710 a and 2710 b and between the casing plate arm 3002 and the boiler casing 2710 .

[0154] To facilitate the installation process, each of the boiler casing segments 2710a and 2710b may be formed to have a gap shape that corresponds to the cross-sectional shape of the casing plate arm 3002. For example, in the example of Figure 32, the downstream boiler casing 2710b may have a triangular gap shape and the upstream boiler casing 2710a may have a rectangular gap shape to accommodate the casing plate arm 3002 when the boiler casing segments 2710a and 2710b are aligned.

[0155] 33A and 33B show a more detailed view of a casing plate according to an exemplary embodiment. The casing plate 3300 can be installed at the lower end of the wellbore 2700. As previously mentioned, the casing plate 3300 can have a number of arms 3302 extending radially outward from a central body 3304. In this non-limiting embodiment, the casing plate 3300 has eight arms generally regularly arranged around the central body 3304. Each of the arms 3302 connects the first boiler casing 2710 with the second boiler casing 2712 to provide support and / or rigidity. The casing plate 3300 can be welded to the first boiler casing 2710 and the second boiler casing 2712 by welds 3302 as shown in more detail in FIG. 33B.

[0156] In this exemplary embodiment, a gap 3304 is maintained between each end of the casing plate arm 3302 and the second boiler casing 2712. The gap 3304 may allow for increased contact between the saturated steam moving through the annular region 2714 and the sidewall of the second boiler casing 2712, thereby increasing the amount of heat transfer.

[0157] In one embodiment, each arm 3302 of the casing plate 3300 has a cross-sectional shape similar to the casing plate arm 3002 shown in Figure 31. Additionally, the cross-sectional area of ​​each arm 3302 can decrease in cross-sectional area as the distance increases from the drill stem 1500. As previously mentioned, the casing plate 3300 can be installed in the connectors between the casing plate segments as described in Figure 32 above.

[0158] FIG 34 is a casing plate according to another exemplary embodiment. The casing plate 3400 has four arms 3402 extending radially outward from a central body portion 3404. The casing plate arms 3400 can have dimensions similar to the casing plate arms 3300 of FIG 33. In one non-limiting embodiment, the distal ends of each of the arms 3402 extend all the way to the second boiler casing 2712 to eliminate the gap shown in FIG 33.

[0159] Figures 35A and 35B show various views of a casing plate according to yet another example embodiment. Figure 35A is a plan view of a casing plate 3500 that may be used as an alternative to casing plate 618 in a cased well, such as cased well 600 of Figure 9A. Figure 35B is an elevation view of casing plate 3500.

[0160] The casing plate 3500 may be positioned such that the fluid conduit 800 may pass through one of the vents 3502. Additionally, the casing plate 3500 may be attached to the inside surface of the boiler casing 602 by welds along its periphery, and the casing plate 3500 may be attached to the drill stem 1500 by welds along the periphery of a central aperture 1500 sized to receive the drill stem. The casing plate 3500 may include a set of vents 3502 having a size and pattern selected to maximize the flow of fluid through the boiler casing 3500. In this exemplary embodiment, the pattern is selected for uniform axial loading.

[0161] 36 is a simplified schematic diagram of another magma power system according to an example embodiment. The magma power system 3600 includes a steam separator 3602 connected directly to a cased well 600 extending between the surface and an underground reservoir of magma. The steam separator 3602 separates the gas phase fluid, i.e., steam, from a condensate formed from the gas phase fluid. Steam lines 3604 are shown as solid lines and condensate lines 3606 are shown as dashed lines.

[0162] A first set of turbines 3608, i.e., high pressure turbines, are connected to the steam separator 3602 and are configured to generate electricity from the vapor phase fluid received from the steam separator 3602. Given a sufficiently high temperature and pressure of the steam generated from the casing well 600, a second set of steam turbines 3610, i.e., low pressure turbines, can be disposed in series with the first set of steam turbines 3608 to generate electricity from the steam exhausted from the first set of steam turbines 3608.

[0163] Although not shown, a condensate tank may be incorporated into the Magma power system 3600 and connected to the condensate line 3606. The condensate may later be injected from the condensate tank back into the cased well 600 for reuse.

[0164] Figure 37 is a schematic diagram of a superheated steam system according to an exemplary embodiment. The superheated steam system 3700 is a schematic diagram of the superheated steam system 1600 of Figure 16. The superheated steam system 3700 includes a casing well 600 extending between the surface of the earth and an underground reservoir of magma. The casing well 600 supplies saturated steam to the superheated steam well 1700. The saturated steam is converted to superheated steam in the superheated steam well 1700, and the superheated steam is transported to a first set of turbines 3706 in a steam line 3702. The steam line 3702 is shown as a solid line and the condensate line 3704 is shown as a dotted line.

[0165] The first set of turbines 3706 are high pressure turbines configured to generate electricity from gas phase fluid received from the superheated steam. Given a sufficiently high temperature and pressure of the steam generated from the superheated steam well 1700, a second set of steam turbines 3708 can be disposed in series with the first set of steam turbines 3706 to generate electricity from the steam exhausted from the first set of steam turbines 3706. As used herein, the second set of turbines 3708 may also be referred to as low pressure turbines because they operate at a lower pressure than the first set of turbines 3706.

[0166] Although not shown, the superheated steam system 3700 may include a condensate tank connected to a condensate line 3704. The condensate may later be injected from the condensate tank back into the casing well 600 for reuse.

[0167] 38A and 38B are cross-sectional views of a wellbore for generating superheated steam according to another exemplary embodiment. In particular, FIG. 38A is a cross-sectional view of wellbore 3800 and FIG. 38B is a cross-sectional view of wellbore 3800 taken along line 38B-38B of FIG. 38A.

[0168] The well 3800 is similar to the well 2700 of FIG. 27, except that the drill stem 1500 and sacrificial bit are withdrawn after drilling of the borehole, and the casing plate 3000 is omitted, instead, a plurality of spacers 3801 are placed between the first boiler casing 3810 and the second boiler casing 3812. An insulating layer 3818 may be wrapped around the second casing 3812 to reduce heat loss. In one embodiment, each of the plurality of spacers 3801 is a fin-shaped protrusion attached to the outer surface of the first boiler casing 3810 using conventional methods such as friction fit, bolting, or welding. In this exemplary embodiment of FIG. 38, the plurality of spacers 3801 are circumferentially placed around the first boiler casing 3810 at various depths of the well 3800. A number of spacers 3801 may also be attached to the ends of the first boiler casing 3810 to maintain separation from the second boiler casing 3812 .

[0169] In certain embodiments, spacers 3801 may be attached to the connector between the two casing segments to improve structural rigidity, however, in an alternative embodiment, the spacers 3801 may be arranged around the outside of the first boiler casing 3810 according to another predetermined pattern, such as a helical pattern similar to the threads of a screw.

[0170] Figure 38B shows a cross-sectional view of the spacer 3801 installed in a wellbore 3900 having a smooth second casing 3812. Figure 39 shows a cross-sectional view of the spacer 3801 installed in a wellbore 3900 having a corrugated second casing 3812.

[0171] Although the embodiments of the present disclosure have been described with reference to some elements, any elements described in the embodiments described herein are exemplary and may be omitted, substituted, added, combined, or rearranged as necessary to form new embodiments. Those skilled in the art will recognize upon reading this specification that further embodiments are effectively disclosed herein. For example, when this disclosure describes features, structures, sizes, shapes, arrangements, or compositions of an element or a process for making or using an element or a combination of elements, these features, structures, sizes, shapes, arrangements, or compositions may also be incorporated into any other element or combination of elements described herein, or into a process for making or using an element or combination of elements to provide further embodiments.

[0172] Furthermore, when an embodiment is described herein as including any element or group of elements, a further embodiment can consist essentially of or consist of the element or group of elements. Similarly, although the open-ended term "comprising" is generally used herein, further embodiments can be formed by replacing it with the term "consisting essentially of" or "consisting of."

[0173] Although the present disclosure has been particularly shown and described with reference to preferred embodiments, those skilled in the art will appreciate that various changes in form and detail may be made in the present disclosure without departing from the spirit and scope of the present disclosure. The inventors anticipate that those skilled in the art will adopt such variations as appropriate, and the inventors intend for the present disclosure to be practiced otherwise than as expressly described herein. Accordingly, the present disclosure includes all modifications and equivalents of the subject matter recited in the claims appended hereto as permitted by applicable law. Moreover, the present disclosure encompasses any combination of the above-described elements in all their possible variations, unless otherwise indicated herein or clearly contradicted by context.

[0174] Further embodiments The following illustrative embodiments are provided in further support of one or more aspects of the present disclosure.

[0175] In a first embodiment, aspects of the disclosure are directed to a system for generating electrical power from an underground reservoir of magma. The system includes a steam separator directly connected to a cased wellbore extending between the earth's surface and the underground reservoir of magma. In some embodiments, the steam separator separates the gas phase fluid from a condensate formed from the gas phase fluid. The system further includes a first set of turbines connected to the steam separator. The first set of turbines is configured to generate electricity from the gas phase fluid received from the steam separator. The system further includes a condensate tank fluidly connected to the steam separator and the first set of turbines. The condensate tank is fluidly connected to a fluid conduit that supplies the condensate to the end of the cased wellbore.

[0176] In another aspect of the first embodiment of the system, the first set of turbines is a high pressure turbine.

[0177] In another aspect of the first embodiment of the system, each of the pair of high pressure turbines generates approximately 200 MW of power.

[0178] In another aspect of the first embodiment of the system, the first set of turbines comprises at least two turbines. In yet another aspect of the first embodiment, the system further comprises a steam supply manifold connected to the steam separator and to each of the at least two turbines.

[0179] In another aspect of the first embodiment, the system includes a second set of turbines connected in series with the first set of turbines.

[0180] In another aspect of the first embodiment of the system, the second set of turbines are low pressure turbines that operate at a lower pressure than the first set of turbines.

[0181] In another aspect of the first embodiment, the system includes a set of heat-driven chillers configured to provide air conditioning from exhaust from the one or more turbines.

[0182] In another aspect of the first embodiment, the system includes one or more fluid conduits configured to convey exhaust from the one or more turbines to an exhaust recycle device.

[0183] In another aspect of the first embodiment, the waste recycle system comprises one or more of a water distillation system, a thermally powered cooling system, a residential heating system, an agricultural system, and an aquaculture system.

[0184] In a second embodiment, an aspect of the disclosure is directed to a method for generating electrical power. The method includes supplying a liquid-phase fluid to a casing wellbore extending from the earth's surface to an underground reservoir of magma. Heat provided from the magma transforms the liquid-phase fluid into a gas-phase fluid that is transported up the casing wellbore to the earth's surface. The method further includes separating the gas-phase fluid from a condensate formed from the gas-phase fluid. The method further includes operating a set of turbines with the gas-phase fluid to generate electricity, accumulating at least a portion of the condensate formed from the gas-phase fluid, and supplying the accumulated condensate as a liquid-phase fluid to the casing wellbore.

[0185] In another aspect of the second embodiment, the set of turbines comprises at least two turbines arranged in series, and operating the set of turbines with gas phase fluid further includes operating an upstream turbine with gas phase fluid at a first pressure, operating a downstream turbine with gas phase fluid received from the upstream turbine at a second pressure lower than the first pressure, and accumulating at least some condensate from the upstream turbine and the downstream turbine for supply to a casing well.

[0186] In another aspect of the second embodiment, the method includes conveying exhaust from the set of turbines to a set of thermally driven chillers configured to provide air conditioning.

[0187] In another aspect of the second embodiment, the method includes conveying exhaust from the set of turbines to an exhaust recycle device.

[0188] In another aspect of the second embodiment, the exhaust recycle system comprises one or more of a water distillation system, a thermally powered chiller, a residential heating system, an agricultural system, a cooling tower, and an aquaculture system.

[0189] In a third embodiment, aspects of the disclosure are directed to a cased wellbore, the cased wellbore comprising: a well casing suspended in a borehole extending between the earth's surface and an underground reservoir of magma; a boiler casing contained within the well casing and extending between the earth's surface and the underground reservoir of magma, the boiler casing having a first end and an end opposite the first end, the end of the boiler casing being immersed in the underground reservoir of magma; a fluid conduit contained within the boiler casing and configured to deliver a liquid-phase fluid to the end of the boiler casing, the temperature and pressure at the end of the boiler casing converting the liquid-phase fluid to a gas-phase fluid that travels through the boiler casing to the earth's surface; and a wellhead connected to the first end of the boiler casing.

[0190] In another aspect of the third embodiment, the well casing extends from the earth's surface to a boundary layer between dry rock and intrusive rock.

[0191] In another aspect of the third embodiment, the boiler casing is coaxially aligned with the well casing. Further, the inner surface of the well casing and the outer surface of the boiler casing define an annular gap.

[0192] In another aspect of the third embodiment, the casing well further comprises an insulating layer within the annular gap spanning a predetermined length of the boiler casing, the predetermined length including the first end of the boiler casing.

[0193] In another aspect of the third embodiment, the boiler casing is formed from a plurality of boiler casing segments arranged end-to-end and welded.

[0194] In another aspect of the third embodiment, the interior volume of the boiler casing is divided into a plurality of compartments by a set of casing plates.

[0195] In another aspect of the third embodiment, each of the set of casing plates includes a plurality of apertures, the plurality of apertures including a first aperture sized to accommodate a fluid conduit, a second aperture sized to receive the drill stem, and a set of steam vents to allow gas phase fluid to travel through the plurality of compartments toward the surface.

[0196] In another aspect of the third embodiment, the casing well further comprises a drill stem extending through the boiler casing from the first end to the distal end and passing through the second aperture in each of the pair of casing plates.

[0197] In another aspect of the third embodiment, an outer surface of the drill stem is welded to each of the pair of casing plates along a periphery of the second aperture.

[0198] In another aspect of the third embodiment, a fluid conduit includes a pipe, an insulating layer surrounding the pipe, and an outer shell surrounding the insulating layer.

[0199] In another aspect of the third embodiment, the ends of the boiler casing are sealed by end plates that include apertures sized to receive the drill stems.

[0200] In another aspect of the third embodiment, a wellhead seals a first end of the boiler casing, the wellhead receiving a fluid conduit and a drill stem.

[0201] In a fourth embodiment, an aspect of the disclosure is directed to a method of forming a cased wellbore extending from the earth's surface to an underground reservoir of magma, the method including drilling a wellbore from the earth's surface toward the underground reservoir of magma, suspending a well casing within the wellbore, responsive to the wellbore reaching a target depth, suspending a boiler casing within the well casing, and resuming drilling of the wellbore from the target depth to a final depth within the underground reservoir of magma, wherein the boiler casing extends from the earth's surface to the final depth within the underground reservoir to form the cased wellbore.

[0202] In another aspect of the fourth embodiment, a well is drilled from the surface to a target depth with a first drill bit connected to the drill stem, and a well casing is transported into the well on an underreamer positioned at a terminal region of the drill stem, and suspending the well casing further includes transporting the well casing into the well while advancing the drill bit toward the subterranean reservoir.

[0203] In another aspect of the fourth embodiment, the method includes suspending a boiler casing within a well casing. The method further includes retracting the underreamer to release the well casing, withdrawing the drill stem and a first drill bit attached to an end of the drill stem, and inserting the boiler casing into the well casing contained within the wellbore.

[0204] In another aspect of the fourth embodiment, the method includes inserting into a well casing, the method further including sealing an end of the boiler casing with an end plate having an aperture sized to receive the drill stem, welding the drill stem to the end plate surrounding a periphery of the aperture, coupling a sacrificial bit to the drill stem, and transporting the end of the boiler casing into the well casing.

[0205] In another aspect of the fourth embodiment, the method includes conveying a distal end of the boiler casing into the well casing, the method further including extending the drill stem and the boiler casing as the distal end of the boiler casing is conveyed into the well casing, the drill stem and the boiler casing being extended from an end of the boiler opposite the distal end of the boiler casing.

[0206] In another aspect of the fourth embodiment, the elongated boiler casing further includes aligning a new boiler casing segment with respect to an end of the boiler casing, and welding the new boiler casing segment to the end of the boiler casing.

[0207] In another aspect of the fourth embodiment, extending the drill stem and the boiler casing further includes fastening a pair of casing plates to a side wall of the boiler casing.

[0208] In another aspect of the fourth embodiment, securing the set of casing plates by the boiler casing further includes welding an outer surface of a drill stem to each of the set of casing plates surrounding a periphery of an aperture sized to receive the drill stem.

[0209] In another aspect of the fourth embodiment, conveying the end of the boiler casing into the well casing further includes drilling from the target depth to a final depth with a sacrificial bit, the sacrificial bit being immersed in an underground reservoir of magma at the final depth.

[0210] In another aspect of the fourth embodiment, conveying the well casing into the wellbore further includes injecting a liquid phase fluid into a distal end of the boiler casing as the boiler casing approaches a final depth.

[0211] In a fifth embodiment, aspects of the disclosure are directed to a cased well for generating superheated steam, the cased well having a first end at the earth's surface, a second end at an underground reservoir of magma, and a fluid passageway extending from an inlet at the first end to the second end and then from the second end to an outlet at the first end, the fluid passageway configured to receive saturated steam at the inlet and discharge superheated steam at the outlet, the saturated steam being converted in the fluid passageway to superheated steam at the second end of the cased well.

[0212] In another aspect of the fifth embodiment, the cased well further comprises a well casing extending from the earth's surface toward the underground reservoir of magma, and the fluid passageway is formed from a set of boiler casings extending through the well casing.

[0213] In another aspect of the fifth embodiment, the casing well bore further comprises a set of boiler casings including a first boiler casing defining a first fluid conduit configured to convey saturated steam from a first end of the casing well bore to a second end of the casing well bore, the set of boiler casings including a second boiler casing defining a second fluid conduit configured to convey superheated steam from the second end of the casing well bore to the first end of the casing well bore.

[0214] In another aspect of the fifth embodiment, the first boiler casing has a first cross-sectional area and the second boiler casing has a second cross-sectional area smaller than the first cross-sectional area, and the second boiler casing is substantially coextensively received within the first boiler casing to define an elongated annular volume of space between an inner surface of a sidewall of the first boiler casing and an outer surface of a sidewall of the second boiler casing.

[0215] In another aspect of the fifth embodiment, the first fluid conduit is an elongated annular volume of space and the second fluid conduit is an elongated volume of space defined by a sidewall of the second boiler casing.

[0216] In another aspect of the fifth embodiment, the first boiler casing has a first cross-sectional area and the second boiler casing has a second cross-sectional area larger than the first cross-sectional area, and the first boiler casing is substantially coextensively received within the second boiler casing to define an elongated annular volume of space between an inner surface of a sidewall of the second boiler casing and an outer surface of a sidewall of the first boiler casing.

[0217] In another aspect of the fifth embodiment, the first fluid conduit is an elongated annular volume of space and the second fluid conduit is an elongated volume of space defined by a sidewall of the first boiler casing.

[0218] In another aspect of the fifth embodiment, the cased well further comprises a wellhead comprising a first connector configured to fluidly connect an inlet of the fluid passage to a source of saturated steam and a second connector configured to fluidly connect an outlet of the fluid passage to a system for generating power from superheated steam.

[0219] In another aspect of the fifth embodiment, the source of saturated steam is an upstream wellbore extending from the earth's surface to the underground reservoir of magma or another underground reservoir of magma.

[0220] In another aspect of the fifth embodiment, the casing well further comprises an inner boiler casing sidewall that is not corrugated at an end of the casing well closest to the second end.

[0221] In another aspect of the fifth embodiment, the sidewall of the inner boiler casing is not corrugated at the end closest to the first end of the casing wellbore.

[0222] In another aspect of the fifth embodiment, the cased wellbore further comprises an insulating layer surrounding the outer boiler casing at the first end.

[0223] In a sixth embodiment, aspects of the disclosure are directed to a system for generating electricity using superheated steam. The system includes a casing well extending between the earth's surface and an underground reservoir of magma. The casing well includes a first end at the earth's surface, a second end at the underground reservoir of magma, and a fluid passage extending from an inlet at the first end to the second end and then from the second end to an outlet at the first end. The fluid passage is configured to receive saturated steam at an inlet and to discharge superheated steam at an outlet. The saturated steam is converted to superheated steam in the fluid passage at the second end of the casing well, and a set of turbines are configured to generate electricity from the superheated steam provided by the casing well.

[0224] In another aspect of the sixth embodiment of the system, the inlet of the fluid passageway receives saturated steam from an upstream wellbore that extends from the earth's surface to the underground reservoir of magma or another underground reservoir of magma.

[0225] In another aspect of the sixth embodiment of the system, the cased well further comprises a well casing extending from the surface toward the underground reservoir of magma, and a fluid passageway is formed from a set of boiler casings extending through the well casing.

[0226] In another aspect of the sixth embodiment of the system, the set of boiler casings includes a first boiler casing defining a first fluid conduit configured to transport saturated steam from a first end of the casing well bore to a second end of the casing well bore, and the set of boiler casings includes a second boiler casing defining a second fluid conduit configured to transport superheated steam from the second end of the casing well bore to the first end of the casing well bore.

[0227] In another aspect of the sixth embodiment of the system, the first boiler casing has a first cross-sectional area, the second boiler casing has a second cross-sectional area smaller than the first cross-sectional area, and the second boiler casing is substantially coextensively received within the first boiler casing to define an elongated annular volume of space between an inner surface of a sidewall of the first boiler casing and an outer surface of a sidewall of the second boiler casing.

[0228] In another aspect of the sixth embodiment of the system, the first fluid conduit is an elongated annular volume of space and the second fluid conduit is an elongated volume of space defined by a sidewall of the second boiler casing.

[0229] In another aspect of the sixth embodiment of the system, the first boiler casing has a first cross-sectional area, the second boiler casing has a second cross-sectional area larger than the first cross-sectional area, and the first boiler casing is substantially coextensively received within the second boiler casing to define an elongated annular volume of space between an inner surface of a sidewall of the second boiler casing and an outer surface of a sidewall of the first boiler casing.

[0230] In another aspect of the sixth embodiment of the system, the first fluid conduit is an elongated annular volume of space and the second fluid conduit is an elongated volume of space defined by a sidewall of the first boiler casing.

[0231] In another aspect of the sixth embodiment, the system further comprises a wellhead comprising a first connector configured to fluidly connect an inlet of the fluid passage to a source of saturated steam and a second connector configured to fluidly connect an outlet of the fluid passage to a system for generating electrical power from superheated steam.

[0232] In a seventh embodiment, an aspect of the disclosure is directed to a method for generating superheated steam, the method including receiving saturated steam from a steam source, conveying the saturated steam into a casing well extending from the earth's surface to an underground reservoir of magma and exposing the saturated steam to heat from the underground reservoir of magma, where the heat from the underground reservoir of magma converts the saturated steam to superheated steam, and conveying the superheated steam back toward the earth's surface.

[0233] In another aspect of the seventh embodiment, conveying the saturated steam into the wellbore further comprises conveying the saturated steam through an annular volume between an outer boiler casing and an inner boiler casing contained within the outer boiler casing. In another aspect of the seventh embodiment, the outer boiler casing is at least partially exposed to magma in the underground reservoir.

[0234] In another aspect of the seventh embodiment of the method, a portion of the sidewall of the inner boiler casing is not corrugated at an end closest to the underground reservoir of magma.

[0235] In another aspect of the seventh embodiment of the method, another portion of the sidewall of the inner boiler casing is not corrugated at the end closest to the ground surface.

[0236] In another aspect of the seventh embodiment of the method, the steam source is an upstream wellbore extending from the earth's surface to the underground reservoir of magma or another underground reservoir of magma.

[0237] In another aspect of the seventh embodiment of the method, the superheated steam is provided to a set of turbines for generating electricity.

Claims

1. 1. A pumping apparatus for a borehole extending from the earth's surface to a subsurface reservoir of very high temperature geothermal fluid (SHGF), comprising: a well screen coupled to an end of a casing string and at least partially immersed in the underground reservoir, the well screen defining a volume of the underground reservoir configured to be at least partially filled by an SHGF through a set of apertures in the well screen; a slidable casing having a first end and a second end, the slidable casing defining an opening at the first end that opens into a cavity bounded by a sidewall and an end wall at the second end, the slidable casing being suspended within the borehole, the slidable casing being coaxially aligned with the well screen; a draw pipe extending through the end wall of the slidable casing and into the volume defined by the well screen; the slidable casing is slidably repositioned to block more of the set of apertures in the well screen; and an increase in pressure within the cavity of the slidable casing; a draw pipe configured to convey the SHGF from the underground reservoir toward the surface in response to A pumping device comprising:

2. 2. The pumping apparatus of claim 1, wherein the slidable casing is slidably repositioned by lowering the slidable casing to cause the cavity in the slidable casing to occupy a larger portion of the volume defined by the well screen within the underground reservoir.

3. 2. The pumping device according to claim 1, A compressor; an inlet pipe connected to the compressor; Further provided with the inlet pipe extends through the end wall of the casing; The end of the inlet pipe is disposed at a predetermined depth; the inlet pipe conveying compressed fluid from the compressor into the borehole to cause an increase in pressure within the cavity of the slidable casing; Pressure feeding device.

4. 4. The pumping device according to claim 3, wherein the compressed fluid is compressed air.

5. 2. The pumping device of claim 1, wherein the slidable casing further comprises a set of adjustable apertures disposed in the end wall to allow passage of a fluid conduit therethrough; each of the adjustable apertures having an open configuration that maintains a gap between the end wall and an outer surface of a corresponding fluid conduit; each of the adjustable apertures having a closed configuration that seals the gap between the end wall and the outer surface of the corresponding fluid conduit to form an airtight seal; Pressure feeding device.

6. 6. The pumping device of claim 5, wherein the set of adjustable apertures is one or more pneumatically operated pipe collar seals configured to reduce an effective diameter of a corresponding aperture through the end wall.

7. The pumping device according to claim 1, a lift coupled to the end wall of the slidable casing, the lift configured to change the depth of the slidable casing; The pumping device further comprises:

8. 8. The pumping device of claim 7, wherein the lift comprises a water hammer or a winch connected to the slidable casing by a set of steel cables.

9. 2. The pumping device of claim 1, wherein the slidable casing comprises: a pressure control valve disposed within the end wall for selectively relieving pressure within the cavity of the slidable casing; The pumping device further comprises:

10. 2. The pumping apparatus of claim 1, wherein the well screen is connected to a well casing suspended within the borehole, the well screen being maintained within an unlined portion of the borehole.

11. 1. A method for pumping ultra-high temperature geothermal fluid (SHGF) through a borehole extending from the earth's surface to a subsurface reservoir, comprising: repositioning a slidable casing within the borehole from an initial position between the surface and the subterranean reservoir to a final position at least partially within the subterranean reservoir; the slidable casing having an opening at a first end leading to a cavity bounded by a sidewall and an end wall at a second end; the slidable casing is coaxially aligned with a well screen at the end of the casing string and is at least partially submerged within the underground reservoir; a well casing having a set of apertures that allow the inflow of SHGF into the volume defined by said well screen; In the final position, the cavity of the slidable casing substantially coincides with the volume defined by the well screen to prevent the flow of SHGF through the set of apertures, and the cavity is filled with the SHGF from the volume defined by the well screen; fixing the slidable casing in the final position within the borehole; increasing pressure within the cavity of the slidable casing to cause the SHGF within the cavity to flow into a draw pipe extending through the end wall of the slidable casing and into the cavity; conveying the SHGF through the draw pipe to the surface; A method comprising:

12. 12. The method of claim 11, repositioning the slidable casing from the final position back to the initial position in response to the cavity being substantially empty of SHGF; allowing the volume defined by the well screen to fill with SHGF before repeating the steps of the method; The method further comprises:

13. 13. The method of claim 12, wherein the step of repositioning the slidable casing from the final position to the initial position comprises: Reducing pressure within the cavity of the slidable casing before sliding the slidable casing. The method further comprises:

14. 14. The method of claim 13, wherein the step of reducing the pressure in the cavity comprises: Opening a pressure control valve or expanding one of a set of adjustable apertures located in the end wall of the slidable casing. The method further comprises:

15. 12. The method of claim 11, wherein the step of repositioning the slidable casing comprises: activating a water hammer to lower the slidable casing from the initial position to the final position; The method further comprises:

16. 12. The method of claim 11, wherein the step of securing the slidable casing comprises: sealing said cavity by actuation of a set of adjustable apertures. The method further comprises:

17. 17. The method of claim 16, wherein the set of adjustable apertures are one or more pneumatically operated pipe collar seals, and the step of sealing the cavity comprises: sealing said one or more pneumatically operated pipe collar seals around fluid conduits passing through said set of adjustable apertures. A method comprising:

18. 12. The method of claim 11, wherein increasing the pressure in the cavity comprises: providing a compressed fluid within the cavity of the slidable casing; The method further comprises:

19. 20. The method of claim 18, wherein the compressed fluid is compressed air, and the step of supplying the compressed fluid comprises: conveying compressed air through an inlet pipe passing through the end wall of the cavity of the slidable casing. A method comprising:

20. 20. The method of claim 19, wherein conveying compressed air through the inlet pipe comprises: The method further includes closing a pressure control valve disposed within the end wall of the slidable casing.

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