PARTIALLY CASED WELLBORE IN MAGMA RESERVOIR

A geothermal system may include a partially cased wellbore. The partially cased wellbore includes a first borehole portion extending from a surface into an underground magma reservoir. The first borehole portion includes a casing extending from a first end. The partially cased wellbore includes a second borehole portion extending from the first end to a terminal end of the wellbore. The second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma.

TECHNICAL FIELD

The present disclosure relates generally to geothermal systems and related methods, and more particularly to geothermal systems and methods using energy from underground magma reservoirs.

BACKGROUND

Solar power and wind power are commonly available sources of renewable energy, but both can be unreliable and have relatively low power densities. In contrast, geothermal energy can potentially provide a higher power density and can operate in any weather condition or during any time of day. However, there exists a lack of tools for effectively harnessing geothermal energy.

SUMMARY

Most existing geothermal energy systems are used for heating applications, such as to heat a home or other space. Where geothermal has been attempted for energy production or other higher temperature applications, previous geothermal systems have required significant expenditure of finances, labor, and equipment, rendering them impractical for commercial development. Most previous geothermal systems tap into low temperature resources of less than 194ºF that are relatively near the surface, significantly limiting applications and locations where previous geothermal systems can be deployed. In addition to other disadvantages of previous geothermal technology, the inability of previous technology to efficiently and reliably access high-temperature underground geothermal resources renders conventional geothermal systems technologically and financially impractical.

As used herein, “magma” refers to extremely hot liquid and semi-liquid rock under the Earth's surface. Magma is formed from molten or semi-molten rock mixture found typically between 1 km to 10 km under the surface of the Earth. As used herein, a “rock plug” refers to a section or volume of rock formed from hardened magma. As used herein, “lava” refers to molten or partially molten rock that has been expelled from the interior of the earth onto its surface extremely hot liquid and semi-liquid rock under the Earth's surface.

As used herein, “borehole” refers to a hole that is drilled to aid in the exploration and recovery of natural resources, including oil, gas, water, or heat from below the surface of the Earth. As used herein, a “wellbore” refers to a “borehole” either alone or in combination with one or more other components disposed within or in connection with the borehole in order to perform exploration and/or recovery processes.

As used herein, “fluid conduit” refers to any structure, such as a pipe, tube, or the like, used to transport fluids. As used herein “drill stem” refers to a drill pipe formed from tool joints, a swivel, a bit, a drill string, drill collars, drives, subs, a top drive, shock absorbers, reamers and any other related equipment used during the drilling process.

As used herein, “heat transfer fluid” refers to a fluid, e.g., a gas or liquid, that takes part in heat transfer by serving as an intermediary in cooling on one side of a process, transporting and storing thermal energy, and heating on another side of a process. Heat transfer fluids are used in processes requiring heating or cooling. As used herein, a “cooling fluid” is a heat transfer fluid used to provide cooling to an area, such as within a borehole.

As used herein “superheated steam” refers to steam at a temperature higher than its vaporization point at the absolute pressure where the temperature is measured.

This disclosure recognizes the previously unidentified and unmet need for a geothermal system that harnesses a geothermal resource with a sufficiently high temperature that can provide a sufficiently high temperature for desired processes. For example, an underground geothermal reservoir, such as a magma reservoir, may facilitate the generation of high-temperature, high-pressure steam, while avoiding problems and limitations associated with previous geothermal technology. The geothermal systems of this disclosure generally include a wellbore that extends from a surface into the underground thermal reservoir. The wellbore may have a variety of features and improvements that are described in more detail below. For example, the wellbore may include a fluid conduit that facilitates improved heat transfer by allowing heat transfer fluid to be in direct or near direct thermal contact with the thermal reservoir and allowing the heated heat transfer fluid to be returned to the surface with fewer thermal losses than are experienced with previous technology. For example, a heat transfer fluid, such as water, can be heated (e.g., converted to steam) and returned to the surface for use in any appropriate high-temperature, high-pressure thermal process, such as energy production, a thermochemical reaction, or the like.

This disclosure also recognizes the previously unidentified and unmet need for a geothermal system that harnesses a geothermal resource with sufficiently high amounts of energy from magmatic activity such that the geothermal resource does not degrade significantly over time. This disclosure illustrates improved systems and method for capturing energy from magma reservoirs, dykes, sills, and other magmatic formations that are significantly higher in temperature than heat sources that are accessed using previous geothermal technologies and that can contain an order of magnitude higher energy density than the geothermal fluids that power previous geothermal technologies. Unlike previous geothermal technologies, certain embodiments of the systems and methods described herein may be resistant to degradation, such that the operating lifetimes of the disclosed systems and methods may be significantly increased over those of previous technologies. The present disclosure may significantly decrease energy production costs and/or reliance on non-renewable resources. In some cases, the present disclosure may facilitate the electrification of regions where access to reliable power is currently unavailable. The systems and methods of the present disclosure may aid in decreasing carbon emissions.

In some cases, the wellbore is cased, or lined by a thermally conductive material that prevents fluid flow between the inside of the wellbore and the surrounding environment, while still allowing heat transfer with the thermal reservoir. For example, the casing may be an alloy sheet with an annular cylinder shape that is attached to the internal surface of a borehole that is drilled to form the wellbore. In other cases, at least a portion of the wellbore that is below a ceiling of thermal reservoir (e.g., within a magma reservoir) does not have a casing. Instead, at the internal surface of the wellbore in this region is made up of magma that is quenched through the supply of an appropriate cooling fluid and/or through the regular or continuous supply of heat transfer fluid into the wellbore. In these partially cased wellbores, heat transfer between the heat transfer fluid introduced into the wellbore and the thermal reservoir is further improved, resulting in the ability to access higher temperatures to support a broader range of thermal processes, such as processes requiring higher energy densities.

In some cases, a pressurized chamber or other vessel is located within the wellbore. The chamber typically extends at least partially into the portion of the wellbore that is within the thermal reservoir. In this way, heat transfer fluid may be provided into the chamber and maintained in thermal contact with the thermal reservoir for a sufficient time and under appropriate conditions to achieve target characteristics, such as a target temperature and pressure. As such, the heat transfer fluid can be adjusted to target conditions to improve or optimize downstream thermal processes.

In some cases, the wellbore may be a directional wellbore in which a number of secondary boreholes may extend from a central or primary borehole that runs from the surface into the thermal reservoir. The network of boreholes formed from the primary and secondary boreholes facilitates improved thermal contact and heat transfer with the thermal reservoir. These directionally drilled wellbores can support high temperature processes at a single well, whereas previous technology may require tens or more of wells to achieve similar levels of power production.

In some cases, a molten salt may be employed as the heat transfer fluid that is provided into the wellbores of any of the geothermal systems described in this disclosure. The use of a molten salt may facilitate operations at higher temperatures than can be achieved using conventional heat transfer fluids and improve overall stability and reliability of geothermal operations.

Certain embodiments may include none, some, or all of the above technical advantages. One or more technical advantages may be readily apparent to one skilled in the art from figures, description, and claims included herein.

DETAILED DESCRIPTION

Embodiments of the present disclosure and its advantages will become apparent from the following detailed description when considered in conjunction with the accompanying figures. In the figures, each identical, or substantially similar component that is illustrated in various figures is represented by a single numeral or notation. For purposes of clarity, not every component is labeled in every figure, nor is every component of each embodiment shown where illustration is not necessary to allow those of ordinary skill in the art to understand the disclosure.

The present disclosure includes unexpected observations, which include the following: (1) magma reservoirs can be located at relatively shallow depths of about 2.1-2.5 km; (2) the top layer of a magma reservoir may have relatively few crystals with little or no mush zone; (3) rock near or around magma reservoirs is generally not ductile and can support fractures; (4) a magma reservoir does not decline in thermal output over at least a two-year period; (5) eruptions at drill sites into magma reservoirs are unlikely (e.g., eruptions have not happened at African and Icelandic drill sites in over 10,000 years and it is believed a Kilauea, Hawaii drill site has never erupted); and (6) drilling into magma reservoirs can be reasonably safe and rising magma can be quenched with water to form a drillable rock plug, as explained further below with respect to the new systems and methods of this disclosure.

FIG.1is a partial cross-sectional diagram of the Earth depicting underground formations that can be tapped by geothermal systems of this disclosure (e.g., for generating geothermal power). The Earth is composed of an inner core102, outer core104, lower mantle106, transition zone108, upper mantle110, and crust112. There are places on the Earth where magma reaches the surface of the crust112forming volcanos114. However, in most cases, magma approaches only within a few miles or less from the surface. This magma can heat ground water to temperatures sufficient for certain geothermal power production. However, for other applications, such as geothermal energy production, more direct heat transfer with the magma is desirable.

FIG.2illustrates a conventional geothermal power generation system200that harnesses energy from heated ground water. The geothermal system200is a “flash-plant” that generates power from a high-temperature, high-pressure geothermal water extracted from a production well202. The production well202is drilled through rock layer208and into the geothermal fluid layer210that serves as the source of geothermal water. The geothermal water is heated indirectly via heat transfer with intermediate layer212, which is in turn heated by magma reservoir214. Convective heat transfer (illustrated by the arrows indicating that hotter fluids rise to the upper portions of their respective layers before cooling and sinking, then rising again) may facilitate heat transfer between these layers. Geothermal water from layer210flows to the surface216and is used for geothermal power generation. The geothermal water (and possibly additional water or other fluids) is then injected back into layer210via injection well210.

The configuration of conventional geothermal system200ofFIG.2suffers from drawbacks and disadvantages, as recognized by this disclosure. For example, because geothermal water is a polyphase fluid (i.e., not pure water), the geothermal water flashes at various points along its path up to the surface216, creating water hammer, which results in a large amount of noise and potential damage to system components. The geothermal water is also prone to cause scaling and corrosion of system components. Chemicals may be added to partially mitigate these issues, but this may result in considerable increases in operational costs and increased environmental impacts, since these chemicals are generally introduced into the environment via injection well204.

Example Improved Geothermal System

FIG.3illustrates an example magma-based geothermal system (or “magma system”)300of this disclosure. The magma system300includes a wellbore302that extends from the surface216at least partially into the magma reservoir214. The magma system300is a closed system in which a heat transfer fluid is provided down the wellbore302to be heated and returned to a thermal or heat-driven process system304(e.g., for power generation and/or any other thermal processes of interest). As such, geothermal water is not extracted from the Earth, resulting in significantly reduced risks associated with the conventional geothermal system200ofFIG.2, as described further below. Heated heat transfer fluid is provided to the heat-driven process system304. The heat-driven process system304is generally any system that uses the heat transfer fluid to drive a process of interest. For example, the heat-driven process system304may be an electricity generation system. Further details of an example heat-driven process system304are provided with respect toFIG.12below and/or support thermal processes requiring higher temperatures/pressures than could be obtained using previous geothermal technology.

The magma system300provides technical advantages over previous geothermal systems, such as the conventional geothermal system200ofFIG.2. The magma system300can achieve higher temperatures and pressures for increased energy generation (and/or for more effectively driving other thermal processes). For example, because of the high energy density of magma in magma reservoir214(e.g., compared to that of geothermal water of layer210), a single wellbore302can generally create the power of many wells of the conventional geothermal system200ofFIG.2. Furthermore, the magma system300has little or no risk of thermal shock-induced earthquakes, which might be attributed to the injection of cooler water into a hot geothermal zone, as is performed using the previous geothermal system200ofFIG.2. The heat transfer fluid is generally not released into the geothermal zone, resulting in a decreased environmental impact and decreased use of costly materials (e.g., chemical additives that are used and introduced to the environment in great quantities during some conventional geothermal operations). The magma system300may also have a simplified design and operation compared to those of previous systems. For instance, fewer components and reduced complexity may be needed at the heat-driven process system304because only clean heat transfer fluid (e.g., steam) reaches the surface216. There is no need to separate out solids or other impurities that are common to geothermal water.

The example magma system300may include further components not illustrated inFIG.3. Further details and examples of different configurations of magma systems and methods of their preparation and operation are described below with respect toFIGS.4A-12.FIGS.4A-6describe an example magma system with a closed flow of heat transfer fluid in more detail.FIGS.7A-9describe another example magma system with a pressurized chamber located down the wellbore.FIGS.10-11describe another example magma system in which a directional wellbore includes secondary boreholes that extend from a primary borehole connecting the surface to the underground magma reservoir.

Example Magma System with Fully or Partially Cased Wellbore

FIG.4Ashows an example magma system400in more detail. The magma system400facilitates the heating of a heat transfer fluid via heat transfer with an underground magma reservoir214. The magma system400includes a wellbore402with a borehole404extending between a surface216and into an underground magma reservoir214. A portion420aof the borehole404is above the magma reservoir214and extends through layers208,210, and212, as described above with respect toFIGS.1and2. Another portion420bof the borehole404extends at least partially into the magma reservoir214. Heat transfer fluid430can be heated to sufficiently high temperatures within portion420bof the borehole404to drive high-temperature processes (e.g., for generating steam for electricity generation, for driving thermochemical reactions, and the like, as described further below).

The magma system400has a closed loop for the flow of heat transfer fluid430into the wellbore402, out of the wellbore402, to a heat-driven process system410(seeFIG.12), and back to the wellbore402. For example, a fluid pump408may provide a flow of heat transfer fluid430toward the underground magma reservoir214. The fluid pump408is any appropriate fluid pump for driving a flow of the heat transfer fluid430. The fluid pump408may pump heat transfer fluid430stored in a fluid source416(e.g., a tank or other canister of the heat transfer fluid430). The heat transfer fluid430may be provided in the liquid phase. An inlet fluid conduit412facilitates flow of heat transfer fluid430into the wellbore402. Fluid pump408may provide heat transfer fluid430at a flow rate to achieve a target temperature via heat transfer with the magma reservoir214(e.g., to achieve a target residence time in the portion420bof the borehole404that extends into the magma reservoir214, to achieve a target temperature and/or pressure of the heat transfer fluid430received at the surface216, etc.). At any given time during operation, a portion of the wellbore402may be filled with heat transfer fluid430as illustrated in the example ofFIG.4A.

The heated heat transfer fluid430may be provided to the heat-driven process system410. The heat-driven process system410may be the same as or similar to the heat-driven process system304ofFIG.3. For example, the heated heat transfer fluid430may be steam or superheated steam that is used to drive one or more turbines for electricity generation. Superheated steam is steam heated above its vaporization pressure at the current pressure. In some cases, the heat transfer fluid430may provide heat to one or more reaction vessels, a water distillation system, a heat-driven chilling apparatus (e.g., for operating condensers), a residential or industrial heating system, an agriculture system, an aquaculture system, or the like. Other examples of heat transfer fluid430and the operation of an example heat-driven process system410are described in greater detail below. Other examples of heat transfer fluids are described in U.S. patent application Ser. No. 18/099,499, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,509, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,514, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,518, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/105,674, filed Feb. 3, 2023, and titled “Wellbore for Extracting Heat from Magma Chambers”; U.S. patent application Ser. No. 18/116,693, filed Mar. 2, 2023, and titled “Geothermal systems and methods with an underground magma chamber”; and U.S. patent application Ser. No. 18/116,697, filed Mar. 2, 2023, and titled “Method and system for preparing a geothermal system with a magma chamber”, the entirety of each of which is incorporated herein by reference.

A return conduit414facilitates the transport of heat transfer fluid430that is cooled by the heat-driven process system410back to the wellbore402. For example, the return conduit414may allow flow of heat transfer fluid430back to the fluid source416(e.g., a fluid storage tank or the like), so that it can be pumped back into the wellbore402using fluid pump408. Fluid conduit412,414(and any other conduit whether labeled or not labeled inFIG.4) may be any appropriate pipes and/or tubes for the flow of heat transfer fluid430between the interconnected components of the magma system400.

The wellbore402includes borehole404, which is a hole drilled from the surface216into the magma reservoir214. The borehole404has an opening at the surface216and an end at a predetermined depth within the underground magma reservoir214. One or more casings418,422may be disposed within the borehole404. A first casing418provides an internal surface within the top portion420aof the wellbore402. Casing418extends from the surface216until a ceiling436of the underground magma reservoir214. The casing418may be any appropriate material for preventing or limiting transport of fluid from the wellbore402to the adjacent layers208,210,212of the Earth. For example, the casing418may be an alloy attached to the wall of the wellbore402. The casing418may be attached with a cement or other appropriate material that has a relatively high thermal conductivity. Examples of hanging the casing418in the borehole404are described further below and with respect toFIG.6. Other details and examples of hanging a casing within a wellbore are described in U.S. patent application Ser. No. 18/099,499, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,509, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,514, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,518, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; and U.S. patent application Ser. No. 18/105,674, filed Feb. 3, 2023, and titled “Wellbore for Extracting Heat from Magma Chambers”.

In some cases, the casing418may extend at least partially into the lower portion420bof the borehole404that extends into the magma reservoir214. For example, a casing422may extend along the surface of the lower portion420bof borehole404. Like casing418, the casing422prevents fluid transport into the adjacent magma reservoir214, while also facilitating efficient heat transfer with magma in the magma reservoir214. The optional casing422in the lower portion420bof the borehole404may be the same as the casing418of the upper portion420aor may be formed of a different material. In some cases, the casing422in the lower portion420bof the borehole404may include materials (e.g., alloys, cements, etc.) with a higher heat resistance (e.g., with a higher melting temperature, degradation temperature, etc.). The surface of the casings418,422may have a surface structure or texture (e.g., rifling) to reduce turbulent flow through the wellbore402.

In some cases, the casings418,422extend no more than partially (or not at all) into the underground magma reservoir214. In such cases, a surface424of the borehole404within the underground reservoir is hardened magma. The hardened magma may be formed by quenching magma in the magma reservoir214with a cooling fluid. Examples of cooling fluids include water, brine, and any of the other heat transfer fluids described in this disclosure. The surface424may be a solidus rock layer, which may include igneous rock formed from hardened magma. The surface424may be igneous rock with no or negligible porosity such that heat transfer fluid430is not significantly transported into the magma reservoir214. When surface424is exposed within the wellbore402, the wellbore402is referred to as being “partially cased” because the casings418,422do not cover all surfaces of the borehole404. For example, the casing418may be disposed on or attached to the first borehole portion420a, while the second borehole portion420bdoes not have casing422. Instead, a surface424of the second borehole portion420bis formed of hardened magma (e.g., magma quenched by a cooling fluid). This disclosure recognizes that a partially cased wellbore may facilitate improved heat transfer between the heat transfer fluid430and the magma reservoir214.

In some cases, the fluid conduit406is a drill stem (e.g., or an outer body of a drill stem) used to form the borehole404. For example, a drill bit426used to drill the borehole404may be removed from the drill stem, such that the drill stem acts as the fluid conduit406. In some cases, the drill bit426may be left attached to the drill stem/fluid conduit406. The fluid conduit406may return heated heat transfer fluid from the wellbore402back to the surface216(as illustrated by the arrows inFIG.4). The fluid conduit406has a hollow center for conveying a fluid (e.g., drilling fluid down the borehole404during drilling operations and heat transfer fluid up the borehole404during other operations). Examples of methods of drilling a borehole404into a magma reservoir214are provided in U.S. patent application Ser. No. 18/099,499, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,509, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,514, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,518, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/105,674, filed Feb. 3, 2023, and titled “Wellbore for Extracting Heat from Magma Chambers”; U.S. patent application Ser. No. 18/116,693, filed Mar. 2, 2023, and titled “Geothermal systems and methods with an underground magma chamber”; and U.S. patent application Ser. No. 18/116,697, filed Mar. 2, 2023, and titled “Method and system for preparing a geothermal system with a magma chamber”.

The fluid conduit406generally includes an attachment interface at the upper end, which is configured for connecting to a wellhead432. The wellhead432includes fluid connections, valves, and the like for facilitating appropriate operation of the wellbore402. For example, the wellhead432may include one or more valves to allow or restrict flow from the wellbore402towards the heat-driven process system410. The wellhead432may include a relief valve for venting heat transfer fluid430if an excessive pressure is reached.

In some cases, the fluid conduit406of the magma system400is configured such that the heat transfer fluid430flows through a fluid pathway in an annulus formed between a wall of the wellbore402and an outer wall of the fluid conduit406.FIG.4Bshows a cross sectional view through line4B-4B ofFIG.4A.FIG.4Bshows the annulus450formed between an inner wall452of the wellbore402and outer wall460of the fluid conduit406(and/or the optional insulation layer428). The annulus450provides an annular pathway for the flow of heat transfer fluid430. The inner wall452may be the surface of a casing418,422or the uncased surface424within the magma reservoir214(described above). An outer wall454contacts the wall of the borehole404, either directly or indirectly, e.g., by way of concrete or other material with a high thermal conductivity for attaching the casing418,422to the wall of the borehole404as previously described. Heat transfer fluid430is transported downward (i.e., toward the magma reservoir214) through the pathway formed by the annulus450. The heated heat transfer fluid430is then returned to the surface through the hollow center456of the fluid conduit406(and/or the optional insulation layer428). The center456is formed within the inner wall458of the fluid conduit406.

Referring again toFIG.4A, the wellbore402may be prepared by drilling the borehole404using a drill bit426(see example method600ofFIG.6). The drill bit426can be attached to a drill stem (e.g., the fluid conduit406) for drilling the wellbore402. The drill bit426can be any appropriate type of currently used or future-developed drill bit for forming the borehole404. For example, the drill bit426may be a tri-cone drill bit with an integrated underreamer (not shown) that projects radially outward to aid in positioning the casing418and/or422within the borehole404. For example, an underreamer may be withdrawn or retracted to allow the drill bit426to be extracted from the borehole404without simultaneously extracting the well casing418and/or422. In some cases, the drill bit426is not extracted from the borehole404but is instead left on or removed from the drill stem (e.g., fluid conduit406) and left at the bottom of the borehole404. This approach of using the drill bit426as a sacrificial drill bit can simplify the drilling process and improve placement of the terminal end434of the fluid conduit406near the bottom of the borehole404.

One or more ejection nozzles (not shown for conciseness) may be positioned on the drill bit426to supply drilling fluid during drilling operations. For example, drilling fluid may be supplied at an increased pressure to improve the removal of material within the borehole404. As another example, cooling fluid may be supplied through the drill bit426to harden magma adjacent to the drill bit426in order to drill into the magma reservoir214(i.e., to form and then drill through a portion of the surface424, described above. Cooling fluid may also or alternatively be supplied through another mechanism, such as down the already drilled portion of the borehole404and/or through nozzles located along the casing418and/or the fluid conduit406. Other details and examples of providing cooling fluid into a wellbore are described in U.S. patent application Ser. No. 18/099,499, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,509, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,514, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/099,518, filed Jan. 20, 2023, and titled “Geothermal Power from Superhot Geothermal Fluid and Magma Reservoirs”; U.S. patent application Ser. No. 18/105,674, filed Feb. 3, 2023, and titled “Wellbore for Extracting Heat from Magma Chambers”; U.S. patent application Ser. No. 18/116,693, filed Mar. 2, 2023, and titled “Geothermal systems and methods with an underground magma chamber”; and U.S. patent application Ser. No. 18/116,697, filed Mar. 2, 2023, and titled “Method and system for preparing a geothermal system with a magma chamber”.

In some cases, the wellbore402can include additional boreholes (not shown in the example ofFIG.4). For example, borehole404may be a primary borehole, and at least one secondary or additional borehole may extend from the primary borehole within the underground magma reservoir214to increase heat transfer between the heat transfer fluid430and the magma reservoir214. An example of such a configuration is illustrated inFIG.10and described in greater detail below.

The heat transfer fluid430may be any appropriate fluid for absorbing heat within the wellbore402and driving a thermal process at the heat-driven process system410. For example, the heat transfer fluid430may include water, a brine solution, one or more refrigerants, a thermal oil (e.g., a natural or synthetic oil), a silicon-based fluid, a molten salt, a molten metal, or a nanofluid (e.g., a carrier fluid containing nanoparticles). The heat transfer fluid430may be selected at least in part to limit the extent of corrosion of surfaces of the magma system400. As an example, when the heat transfer fluid430is used to drive electricity-generating turbines (seeFIG.12), the heat transfer fluid430may be water. The water is supplied in the liquid phase and is transformed into steam within the wellbore402. The steam can be used to drive turbines for electricity generation.

In some cases, such as to facilitate thermochemical processes requiring higher temperatures than can be achieved using steam or other typical heat transfer fluids, a molten salt heat transfer fluid430may be used. A molten salt is a salt that is a liquid at the high operating temperatures experienced in the magma system400(e.g., at temperatures between 1,600 and 2,300 ºF). In some cases, an ionic liquid may be used as the heat transfer fluid430. An ionic liquid is a salt that remains a liquid at more modest temperatures (e.g., at or near room temperature). In some cases, a nanofluid may be used as the heat transfer fluid430. The nanofluid may be a molten salt or ionic liquid with nanoparticles, such as graphene nanoparticles, dispersed in the fluid. Nanoparticles have at least one dimension of 100 nanometers (nm) or less. The nanoparticles increase the thermal conductivity of the molten salt or ionic liquid carrier fluid. This disclosure recognizes that molten salts, ionic liquids, and nanofluids can provide improved performance as heat transfer fluids in the magma systems described in this disclosure (seeFIGS.3,4A,7A, and10). For example, molten salts and/or ionic liquids may be stable at the high temperatures that can be reached in a wellbore that extends into a magma reservoir214. The high temperatures that can be achieved by these materials not only facilitate increased energy extraction but also can drive thermal processes that were previously inaccessible using previous geothermal technology.

In an example operation of the magma system400, a heat transfer fluid430is stored in a fluid source416. The fluid pump408pumps the heat transfer fluid430into the wellbore402. For example, the heat transfer fluid430may be pumped through inlet conduit412into an annulus450between the internal or inner wall452of the wellbore402and the external wall460of the fluid conduit406(seeFIG.4B). The heat transfer fluid430travels into the wellbore402and increases in temperature. The heat transfer fluid430may vaporize and increase in pressure. In some cases, the heat transfer fluid430may be superheated. A superheated liquid is a liquid that is heated above its boiling point. A superheated vapor is a material that is in the vapor phase and heated above its vaporization point at a given pressure.

The rate at which the heat transfer fluid430is supplied into the wellbore402can be adjusted to control the residence time of the heat transfer fluid430in the wellbore402, or more particularly in the portion420bof the wellbore402that extends into the magma reservoir214. The rate at which the heat transfer fluid430is flowed into the wellbore402may also be adjusted to reach a target pressure/temperature in the wellbore402, at the surface216, and/or at the heat-driven process system410. For example, the flow rate of a water heat transfer fluid430may be adjusted to generate steam at a target pressure for use in the heat-driven process system410.

The heated heat transfer fluid430(whether still a liquid, a vapor/liquid mixture, a vapor, or a superheated liquid or vapor) then flows back toward the surface216. For example, the heated heat transfer fluid430may flow through the center of the fluid conduit406. The temperature of the heat transfer fluid430may decrease to some extent while flowing back towards the surface (e.g., via heat transfer with the cooler heat transfer fluid430at a higher level in, or more recently introduced into, the wellbore402). The insulation layer428may help mitigate against this decrease in temperature. Overall, the amount of temperature decrease experienced in the fluid conduit406can be accounted for, such that the heat transfer fluid430is heated to a temperature in excess of what is needed at the heat-driven process system410. In this way, the heat transfer fluid430can still be at the desired conditions of temperature and/or pressure upon reaching the heat-driven process system410. The wellhead432may include valves to further adjust the pressure in the wellbore402.

After reaching the surface216, the heated heat transfer fluid430is directed to the heat-driven process system410. Details of an example heat-driven process system410are provided below with respect toFIG.12. However, as a brief example, the heat-driven process system410may include one or more electricity-generating turbines. A vapor portion of the heated heat transfer fluid430is provided to the turbine(s) and used to generate electricity. The heat transfer fluid430is cooled and condensed during this process (or through subsequent processes), and the cooled, condensed heat transfer fluid430is returned to the fluid source416via conduit414. The heat transfer fluid430can then be returned to the wellbore402to repeat the cycle described above.

Example Methods of Using and Preparing Magma System with a Fully or Partially Cased Wellbore

FIG.5illustrates an example method500of operating the magma system400ofFIG.4A. The method500may begin at step502where heat transfer fluid430is provided down the wellbore402. For example, the fluid pump408may pump the heat transfer fluid430into the wellbore402, as described above with respect toFIGS.4A and4B. At step504, heat transfer fluid430heated in the wellbore402is received at the surface216. At step506, the heated heat transfer fluid430is provided to the heat-driven process system410. For example, at least a vapor portion of the heat transfer fluid430may be provided to turbine(s) that is/are operated to generate electricity. At step508, at least a portion of the heat transfer fluid430from the heat-driven process system410is provided back down the wellbore402(e.g., after the heat transfer fluid430is cooled and condensed).

FIG.6illustrates an example method600of preparing the magma system400ofFIG.4A. The method600may begin at step602where a portion of the borehole404is drilled. For example, a predefined depth or distance into the ground may be drilled using the drill bit426. If a casing418,422is desired at the depth, the casing418,422is hung along the drilled portion of the borehole404at step604. The casing418,422may be hung while or after advancing the drill bit426. At step606, a determination is made of whether the underground magma reservoir214has been reached. If the magma reservoir214has not been reached, operations return to step602to continue drilling the borehole404at step602. If the magma reservoir214has been reached, the method proceeds to step608.

At step608, magma in the magma reservoir214is quenched with a cooling fluid and is drilled. Cooling fluid may be supplied through nozzles in the drill bit426, the drill stem/fluid conduit406, and/or the borehole404that has already been drilled. The quenched magma hardens to form a rock plug that can be drilled into and removed using the drill bit426. This operation continues until a target depth is reached. Once the target depth is reached within the magma reservoir214, the drill bit426may be disconnected at step610. For example, the drill bit may be disconnected and allowed to remain at the bottom of the borehole404as shown in the example ofFIG.4Aor the drill stem/fluid conduit406may be retracted to recover the drill bit426. If the drill bit is recovered, the fluid conduit406is placed within the borehole404.

At step612, a cooling fluid is provided down the borehole404to ensure that the surface424remains hardened. At step614, the drill stem/fluid conduit406is fluidly connected to the heat-driven process system410. For example, the fluid conduit406may be connected to a wellhead432which is in turn in fluid communication with the heat-driven process system410. Any appropriate fluid connections may be used. The resulting magma system400can then be used to perform the steps of method500ofFIG.5, described above and any other operations described in this disclosure.

Modifications, omissions, or additions may be made to methods500,600depicted inFIGS.5and6, respectively. Methods500,600may include more, fewer, or other steps. For example, at least certain steps may be performed in parallel or in any suitable order. While at times discussed as magma system400performing steps, any suitable component of the magma system400or other components of a geothermal system may perform or may be used to perform one or more steps of the methods500,600.

Example Magma System with Downhole Chamber for Heating and Pressurization

In some cases, a magma system, such as the magma system300ofFIG.3includes a dedicated chamber for heating and/or pressurizing a heat transfer fluid to target conditions.FIG.7Aillustrates an example of such a magma system700with a chamber704located within the borehole404. Example magma system700includes many of the same components and structures of example magma system400ofFIG.4A, which function the same or similarly to as described above with respect toFIGS.4A-6unless indicated otherwise. However, in the magma system700, the wellbore702includes a chamber704located within the borehole404. The chamber extends at least partially into the underground magma reservoir214(i.e., the chamber is at least partially positioned in the lower portion420bof the borehole404). In the magma system700, the inlet conduit412facilitates flow of heat transfer fluid430from the surface216and into the chamber704. The fluid conduit406facilitates flow of heated heat transfer fluid430from the chamber704toward the surface216.

The magma system700may facilitate improved control of the properties of the heat transfer fluid430that can be obtained from the wellbore702. For example, the pressure of the heat transfer fluid430in the chamber704can be controlled to facilitate the preparation of a heat transfer fluid430(e.g., steam) at a desired temperature and pressure for use in the heat-driven process system410. For instance, a valve706may be positioned to open to allow flow of the heated heat transfer fluid through the outlet conduit when a pressure in the chamber is at least a threshold value. The valve706may allow control of the residence time of heat transfer fluid430in the chamber704. The residence time can be adjusted to achieve a desired temperature and/or pressure of heat transfer fluid430. The valve706may be a check valve that opens after a predefined pressure is reached in the chamber704. The valve may be an electromechanical valve that can be opened based on a signal (e.g., provided by control electronics, not shown for conciseness). For example, the valve706may open when a threshold temperature and/or pressure is measured in the chamber704(e.g., using a thermocouple or any other appropriate temperature sensor placed on, in, or adjacent to the chamber704). The threshold pressure and/or temperature for opening the valve706to allow flow of heated and pressurized heat transfer fluid430toward the surface216may be adjusted based on needs at the surface216. For example, if the heat-driven system410is an electricity generation system, higher pressures may be requested in the chamber704when electricity demand is increased. An increased pressure may facilitate increased electricity generation.

The chamber704is generally any appropriate vessel for storing heat transfer fluid430. The chamber704may be made of a high-melting point alloy or other material that is stable at the relatively high temperatures experienced in the borehole404. The chamber704is generally in thermal contact with the magma reservoir214. For example, the outer surface of the chamber704may be in direct or indirect contact with the surface424of the bottom portion420bof the borehole404or a casing422disposed in portion420b. An air gap may not be present between the outer surface of the chamber704and the casing422/surface424. Instead, one or more thermally conductive materials may be disposed between the outer wall of the chamber704and the surface424and/or casing422to facilitate efficient heat transfer between the magma reservoir214and the chamber704. In some cases, the chamber704may be surrounded by a thermally conductive fluid that facilitates heat transfer between the magma reservoir214and the chamber704. In some cases, surface424is allowed to melt, such that the chamber704is partially surrounded by magma.

As described above, one or more thermally conductive materials may be employed to connect the chamber704to the internal surface424or casing422. Exploded views of region710ofFIG.7Aare shown inFIGS.7B and7C.FIGS.7B and7Cillustrate example interfaces between the chamber704and magma reservoir214in region710.FIG.7Billustrates the thermal contact between the chamber704and magma reservoir214when the wellbore702is partially cased (seeFIG.4Aand corresponding description above), whileFIG.7Billustrates this thermal contact for a cased wellbore702. In the illustrative example ofFIG.7B, a thermally conductive material714provides contact between the wall712of the chamber704and the surface424of the magma reservoir214. The thermally conductive material714may be a thermally conductive cement. The thermally conductive material714provided down the wellbore702to provide improved thermal contact between the chamber704and magma reservoir214. In the illustrative example ofFIG.7C, the thermally conductive material714provides contact between the wall712of the chamber704and the casing422attached to the surface424of the magma reservoir214. The thermally conductive material714may be the same as described above with respect toFIG.7B. An additional layer of thermally conductive material716connects the casing422to the surface424of the wellbore702. Material716may be a thermally conductive cement or similar material.

Referring again toFIG.7A, in an example operation of the magma system700, a heat transfer fluid430is stored in a fluid source416. The fluid pump408pumps the heat transfer fluid430into the chamber704. For example, the heat transfer fluid430may be pumped through inlet conduit412into the chamber704. The heat transfer fluid430may be temporarily stored in the chamber704while heat transfer with the magma reservoir214increases the temperature and pressure of the heat transfer fluid430. For example, valve706may prevent the heat transfer fluid430from exiting the chamber704until at least a threshold or target pressure/temperature is reached. As an example, if water heat transfer fluid430is provided to the chamber704, the water may be heated and transformed into steam. The steam may not be released from the chamber704until at least a threshold pressure is reached. In some cases, the steam heat transfer fluid430may be superheated. In some cases, the rate at which the heat transfer fluid430is supplied into the wellbore402is adjusted to control the residence time of the heat transfer fluid430in the chamber704and/or adjust the pressure of the heat transfer fluid430in the chamber704.

The heated, pressurized heat transfer fluid430then flows back toward the surface216. For example, the heated heat transfer fluid430may flow through the fluid conduit406. The temperature and pressure of the heat transfer fluid430may decrease to some extent while flowing back towards the surface (e.g., via heat transfer with the cooler environment at a higher level in the wellbore702). The insulation layer428may help mitigate this decrease in temperature and pressure. Overall, the amount of temperature decrease experienced in the fluid conduit406can be accounted for, such that the heat transfer fluid430is heated to a temperature and pressure in the chamber704that is in excess of what is needed at the heat-driven process system410. In this way, the heat transfer fluid430can still be at the desired conditions of temperature and/or pressure upon reaching the heat-driven process system410.

After reaching the surface216, the heated, pressurized heat transfer fluid430is directed to the heat-driven process system410. Details of an example heat-driven process system410are provided below with respect toFIG.12. However, as a brief example, the heat-driven process system410may include one or more electricity-generating turbines. A vapor portion of the heated heat transfer fluid430is provided to the turbine(s) and used to generate electricity. The heat transfer fluid430is cooled and condensed during this process (or through subsequent processes), and the cooled, condensed heat transfer fluid430is returned to the fluid source416via conduit414. The heat transfer fluid430can then be returned to the chamber704to repeat the cycle described above.

Example Methods of Using and Preparing Magma System with Downhole Chamber

FIG.8shows an example method800of preparing the magma system700ofFIG.7A. The method800may begin at step802where the wellbore702is prepared. For example, the borehole404may be drilled into the magma reservoir214and a casing418and/or422may be placed in the reservoir. Preparation of wellbore702may be achieved using steps of the method600ofFIG.6with or without modification. At step804, the chamber704is placed in the wellbore702. For example, the chamber704may be lowered into the wellbore702at a desired depth (e.g., to achieve desired temperature/pressure conditions based on heat transfer with the magma reservoir214). At step806, the chamber704is placed in thermal contact with the magma reservoir214, as described above with respect toFIGS.7A-C. For example, one or more thermally conductive layers (e.g., of materials714and/or716—seeFIGS.7B and7C) may be used to place the chamber704in thermal contact with the magma reservoir214. Fluid conduits412and406are connected to the chamber704.

FIG.9shows an example method900of operating the example magma system700ofFIG.7A. The method900may begin at step902where heat transfer fluid430is provided to the chamber704in wellbore702. For example, the fluid pump408may pump the heat transfer fluid430into the chamber704, as described above with respect toFIG.7A. At step904, heat transfer between the chamber704and the magma reservoir214is allowed to heat the heat transfer fluid430in the chamber704. At step906, a determination is made of whether a threshold or target pressure has been achieved in the chamber704. If this is not the case, further heat transfer is allowed by returning to step904, such that the heat transfer fluid430can increase in temperature and pressure in the chamber704.

If the threshold or target pressure is achieved at step906, the method900proceeds to step908where the heated, pressurized heat transfer fluid430is allowed to return to the surface216(e.g., via fluid conduit406). At step910, the heated heat transfer fluid430is provided to the heat-driven process system410. For example, at least a vapor portion of the heat transfer fluid430may be provided to turbine(s) that is/are operated to generate electricity. At step912, at least a portion of the heat transfer fluid430from the heat-driven process system410is provided back to the chamber704(e.g., after the heat transfer fluid430is cooled and condensed).

Modifications, omissions, or additions may be made to methods800,900depicted inFIGS.8and9, respectively. Methods800,900may include more, fewer, or other steps. For example, at least certain steps may be performed in parallel or in any suitable order. While at times discussed as magma system700performing steps, any suitable component of the magma system700or other components of a geothermal system may perform or may be used to perform one or more steps of the methods800,900.

Example Magma System with Secondary Borehole(s)

In some cases, a magma system, such as the magma system300ofFIG.3and magma system400ofFIG.4Aincludes one or more secondary boreholes extending from a primary borehole.FIG.10illustrates an example of such a magma system1000with secondary boreholes1006a-cextending from the primary borehole1004, which may be the same as or similar to borehole404ofFIG.4A). Example magma system1000includes many of the same components and structures of example magma system400ofFIG.4A, which function the same or similarly to as described above with respect toFIGS.4A-6unless indicated otherwise. However, in the magma system1000, the wellbore1002includes the primary borehole1004with an opening at the surface216and an end1016at a predetermined depth within the underground magma reservoir214as well as at least one secondary borehole1006a-cextending from the primary borehole1004further into the underground magma reservoir214.

The primary borehole1004can be fully or partially cased. For example, as described with respect to the magma system400ofFIG.4A, a casing (not shown for clarity and conciseness) may be applied to all or a portion of the primary borehole1004. The casing418may extend at least until about the ceiling436of the magma reservoir214. The casing418may extend at least partially into the lower portion420bof the primary borehole1004.

The secondary boreholes1006a-cmay extend in a number of directions and/or angles from the primary borehole1004. The secondary boreholes1006a-cmay have an internal wall or surface424formed of hardened magma, similarly to as described above with respect toFIG.4A. For example, one or more secondary boreholes, such as example secondary borehole1006amay extend horizontally (e.g., at about 90 degrees relative to the direction1008of the primary borehole1004). For example, secondary borehole1006aextends from the primary borehole1004at an angle1010relative to a direction1008of the primary borehole1004. Direction1008is generally a downward direction extending from the surface216to the end1016of the primary borehole1004. In some cases, a secondary borehole may extend from a secondary borehole. The additional secondary borehole1006bextends at an angle1012relative to the secondary borehole1006a. One or more secondary boreholes may extend at angles either extending deeper into the Earth or slanting back towards the surface216. For example, as shown in the example ofFIG.10, a secondary borehole1006cextends at an angle1014relative to the direction1008of the primary borehole1004. Secondary borehole1006cchanges direction along its length.

Although shown for the sake of clarity and conciseness as beginning from within the magma reservoir214, one or more secondary boreholes1006a-cmay begin from a position above the magma reservoir214, such from any of the higher layers208,210,212, and extend into the magma reservoir214or to another desired depth. Overall, the primary borehole1004and secondary boreholes1006a-cmay form a network of interconnected boreholes such that there is an increased surface area within the magma reservoir214for heat transfer between the magma reservoir214and the heat transfer fluid430provided down the wellbore1002. The size and shape of this network (e.g., the length, direction, number of branches, etc.) may be determined to improve heat transfer based on the shape of the magma reservoir214or the thermal requirements of the heat-driven process system410. In some cases, a single fluid conduit similar to inlet conduit412ofFIG.4Amay supply heat transfer fluid430into the wellbore1002. However, as illustrated inFIG.10, it may be advantageous to include multiple inlet conduits412a,bto help facilitate the flow of heat transfer fluid430into the secondary boreholes1006a-c. For example,FIG.10illustrates an example configuration in which a first inlet conduit412aprovides a flow of heat transfer fluid430into secondary borehole1006c, while another inlet fluid conduit412bprovides a flow of heat transfer fluid430into secondary boreholes1006aand1006b. In some cases, inlet conduits412a,bmay include bifurcations with multiple outlets to facilitate flow to multiple secondary boreholes1006a-c.

In an example operation of the magma system1000, a heat transfer fluid430is stored in a fluid source416. The fluid pump408pumps the heat transfer fluid430into the wellbore1002. For example, the heat transfer fluid430may be pumped through inlet conduits412a/412band into one or more of the secondary boreholes1006a-cwhere heat transfer occurs between the heat transfer fluid430and the magma reservoir214. The heat transfer fluid430travels through the secondary boreholes1006a-cand towards the primary borehole1004where heat transfer can continue to occur. This heat transfer increases the temperature of the heat transfer fluid430. The pressure of the heat transfer fluid430may also be increased. For instance, water heat transfer fluid430may be transformed into steam at an increased pressure. The steam heat transfer fluid430may be superheated. The rate at which the heat transfer fluid430is supplied into the wellbore1002can be adjusted to control the residence time of the heat transfer fluid430in the wellbore1002, or more particularly in the portion420bof the wellbore1002that extends into the magma reservoir214(e.g., in the network of secondary boreholes1006a-c).

The heated heat transfer fluid430then flows back toward the surface216. For example, the heated heat transfer fluid430may flow through the fluid conduit406. An insulation layer428may help mitigate against a decrease in temperature and/or pressure of the heat transfer fluid430as it travels towards to the surface216. Overall, the amount of temperature decrease experienced in the fluid conduit406can be accounted for, such that the heat transfer fluid430is heated to a temperature and/or pressure in excess of what is needed at the heat-driven process system410. In this way, the heat transfer fluid430can still be at the desired conditions of temperature and/or pressure upon reaching the heat-driven process system410. The wellhead432may include valves to further adjust the pressure in the wellbore1002.

After reaching the surface216, the heated heat transfer fluid430is directed to the heat-driven process system410(seeFIG.12). As a brief example, the heat-driven process system410may include one or more electricity-generating turbines. A vapor portion of the heated heat transfer fluid430is provided to the turbine(s) and used to generate electricity. The heat transfer fluid430is cooled and condensed during this process (or through subsequent processes), and the cooled, condensed heat transfer fluid430is returned to the fluid source416via conduit414. The heat transfer fluid430can then be returned to the wellbore1002to repeat the cycle described above.

Example Methods of Using and Preparing Magma System with Secondary Borehole(s)

FIG.11shows an example method1100for preparing the wellbore1002ofFIG.10. The method1100may begin at step1102where the primary borehole1004is drilled into the magma reservoir214. The primary borehole1004may be drilled as described above with respect toFIG.6. At step1104, the one or more secondary boreholes1006a-care drilled. For example, after all or at least a portion of the primary borehole1004is drilled, the drill bit426may be adjusted to a desired angle for producing a secondary borehole1006a-c. For instance, secondary borehole1006amay be drilled by rotating the drill bit426to drill at angle1010. When the secondary borehole1006ais complete, the drill bit426may be backed out through borehole1006auntil the position of borehole1006b. The drill bit may then be rotated by angle1012, and borehole1006bmay be drilled. The drill bit426may then be backed out of boreholes1006band1006aand rotated to angle1014relative to the direction1008of the primary borehole1004. Borehole1006cmay then be drilled. The drill bit426may then be backed out and removed as shown inFIG.10, removed and allowed to remain within the wellbore1002, left on the drill stem/fluid conduit406, or removed from the wellbore1002. In some cases, multiple drill bits426may be employed to drill one or more of the boreholes1004,1006a-c, as appropriate. Any directional drilling technique currently available or developed in the future may be employed to drill boreholes1004,1006a-c. The resulting magma system1000may be operated as described above with respect toFIG.10and/or according to the method500ofFIG.5.

Modifications, omissions, or additions may be made to method1100depicted inFIG.11. Method1100may include more, fewer, or other steps. For example, at least certain steps may be performed in parallel or in any suitable order. While at times discussed as magma system1000performing steps, any suitable component of the magma system1000or other components of a geothermal system may perform or may be used to perform one or more steps of the method1100.

Example Heat-Driven Process System

FIG.12shows a schematic diagram of an example heat-driven process system304,410of this disclosure. The heat-driven process system304,410includes a condenser1202, a first turbine set1204, a second turbine set1208, a high-temperature/pressure thermochemical process1212, a medium-temperature/pressure thermochemical process1214, and one or more lower temperature/pressure processes1216a-b. The heat-driven process system304,410may include more or fewer components than are shown in the example ofFIG.12. For example, a heat-driven process system304,410used for power generation alone may omit the high-temperature/pressure thermochemical process1212, medium-temperature/pressure thermochemical process1214, and lower temperature/pressure processes1216a-b. Similarly, a heat-driven process system304,410that is not used for power generation may omit the turbine sets1204,1208. As a further example, if heat transfer fluid430is known to be received only in the gas phase, the condenser1202may be omitted in some cases. The ability to tune the properties of the heat transfer fluid430received from the unique wellbores402,702,1002described in this disclosure generally facilitates improved and more flexible operation of the heat-driven process system304,410. For example, the depth of the wellbore402,702,1002, the residence time of heat transfer fluid430in the wellbore402,702,1002, the pressure achieved in the wellbore402,702,1002and/or downhole chamber704, the number and length of secondary boreholes1006a-cin wellbore1002, and the like can be selected or adjusted to provide desired heat transfer fluid properties at the heat-driven process system304,410.

In the example ofFIG.12, the condenser1202is connected to the wellbore402,702,1002that extends between a surface and the underground magma reservoir. The condenser1202separates a gas-phase heat transfer fluid430(e.g., steam) from liquid-phase heat transfer fluid430(e.g., condensate formed from the gas-phase heat transfer fluid430). The condenser1202may be a steam separator. A stream1220received from the wellbore402,702,1002may be provided to the condenser1202. In some cases, all of stream1218is provided in stream1220. In other cases, a fraction or none of stream1218is provided to the condenser1202. Instead, all or a portion of the stream1218may be provided as stream1228which may be provided to the first turbine set1204and/or to a high-pressure thermal process1212in stream1229. The thermal process1212may be a thermochemical reaction requiring high temperatures and/or pressures (e.g., temperatures of between 500 and 2,000° F. and/or pressures of between 1,000 and 4,500 psig). One or more valves (not shown for conciseness) may be used to control the direction of stream1220to the condenser1202, first turbine set1204, and/or thermal process1212. A gas-phase stream1222of heat transfer fluid430from the condenser may be sent to the first turbine set1204and/or the thermal process1212via stream1226. A liquid-phase stream1224of heat transfer fluid430from the condenser1202may be provided back to the wellbore402,702,1002(e.g., or to a fluid source416—seeFIGS.4A,7A, and10).

The first turbine set1204includes one or more turbines1206a-b. In the example ofFIG.12, the first turbine set includes two turbines1206a-b. However, the first turbine set1204can include any appropriate number of turbines for a given need. The turbines1206a-bmay be any known or yet to be developed turbine for electricity generation. The turbine set1204is connected to the condenser1202and is configured to generate electricity from the gas-phase heat transfer fluid430(e.g., steam) received from the condenser1202(stream1222). A condensate stream1230exits the set of turbines1204. The condensate stream1230may be provided back to the wellbore402,702,1002(e.g., sent to the fluid source416ofFIGS.4A,7A, and10).

If the heat transfer fluid430is at a sufficiently high temperature, as may be uniquely and more efficiently possible using the wellbores402,702,1002of this disclosure, a stream1232of gas-phase heat transfer fluid430may exit the first turbine set1204. Stream1232may be provided to a second turbine set1208to generate additional electricity. The turbines1210a-bof the second turbine set1208may be the same as or similar to turbines1206a-b, described above.

All or a portion of stream1232may be sent as gas-phase stream1234to a thermal process1214. Process1214is generally a process requiring gas-phase heat transfer fluid430at or near the conditions of the heat transfer fluid exiting the first turbine set1204. For example, the thermal process1214may include one or more thermochemical processes requiring steam or another heat transfer fluid430at or near the temperature and pressure of stream1232(e.g., temperatures of between 250 and 1,500° F. and/or pressures of between 500 and 2,000 psig). The second turbine set1208may be referred to as “low pressure turbines” because they operate at a lower pressure than the first turbine set1204. Condensate from the second turbine set1208is provided back to the wellbore402,702,1002via stream1236.

An effluent stream1238from the second turbine set1208may be provided to one or more thermal process1216a-b. Thermal processes1216a-bgenerally require less thermal energy than processes1212and1214, described above (e.g., processes1216a-bmay be performed temperatures of between 220 and 700° F. and/or pressures of between 15 and 120 psig). As an example, processes1216a-bmay include water distillation processes, heat-driven chilling processes, space heating processes, agriculture processes, aquaculture processes, and/or the like. For instance, an example heat-driven chiller process1216amay be implemented using one or more heat driven chillers. Heat driven chillers can be implemented, for example, in data centers, crypto-currency mining facilities, or other locations in which undesirable amounts of heat are generated. Heat driven chillers, also conventionally referred to as absorption cooling systems, use heat to create chilled water. Heat driven chillers can be designed as direct-fired, indirect-fired, and heat-recovery units. When the effluent includes low pressure steam, indirect-fired units may be preferred.

At least one advantage of using the heat-driven process system304,410in combination with the improved magma systems300,400,700,1000of this disclosure is the ability to achieve an increased efficiency, which can be attributed, for example, to a simpler operational design with fewer parasitic loads such as from pumps and thermal losses (e.g., through the use of multiple heat exchange processes, rather than using the heat transfer fluid430that is heated in the wellbore402,702,1002directly in the heat-driven process system304,410). The superior heat source embodied by the example wellbores402,702,1002of this disclosure provide a higher ratio of usable energy to entropy than was possible using previous geothermal technology. Another example technical advantage of the magma systems of this disclosure is the ability implement multiple processes in series, such that remaining steam or other relatively high temperature and pressure heat transfer fluid from one process can be used in another down-stream process. This may also decrease energy expended to cool heat transfer fluid before it is returned to the wellbore402,702,1002. An effluent stream1240from processes1212,1214, and/or1216a-bmay be provided back to wellbore302,402,702,1002.

This disclosure describes example systems300,400,700,1000that may facilitate improved geothermal operations. While these example systems300,400,700,1000are described as employing heating through thermal contact with a magma reservoir214, it should be understood that this disclosure also encompasses similar systems in which another thermal reservoir or heat source is harnessed. For example, heat transfer fluid may be heated by underground water at an elevated temperature. As another example, heat transfer fluid may be heated by radioactive material emitting thermal energy underground or at or near the surface. As yet another example, heat transfer fluid may be heated by lava, for example, in a lava lake or other formation. As such, the magma reservoir214ofFIGS.3,4A,7A, and10may be any thermal reservoir or heat source that is capable of heating heat transfer fluid to achieve desired properties (e.g., of temperature and pressure). Furthermore, the thermal reservoir or heat source may be naturally occurring or artificially created (e.g., by introducing heat underground that can be harnessed at a later time for energy generation or other thermal processes).

ADDITIONAL EMBODIMENTS

The following descriptive embodiments are offered in further support of the one or more aspects of the disclosure.

Embodiment 1. A geothermal system for obtaining heated heat transfer fluid via heat transfer with an underground reservoir of magma, the geothermal system comprising:a wellbore extending between a surface and into the underground reservoir of magma;a fluid pump configured to provide a flow of heat transfer fluid toward the underground reservoir of magma; anda fluid conduit extending from the surface toward a terminal end of the wellbore, the fluid conduit configured to allow flow of heated heat transfer fluid from a portion of the wellbore that extends into the underground reservoir of magma toward the surface, wherein the geothermal system optionally includes any one or more following limitations:wherein the fluid pump is configured to provide the flow of the heat transfer fluid through an annulus formed between a wall of the wellbore and an outer wall of the fluid conduit;wherein the fluid conduit comprises a drill stem positioned within the wellbore;wherein the wellbore comprises:a borehole with an opening at the surface and an end at a predetermined depth within the underground reservoir of magma; anda casing disposed within the borehole and extending from the surface until at least a ceiling of the underground reservoir of magma;wherein the casing extends into the underground reservoir of magma;wherein the casing extends no more than partially into the underground reservoir of magma, wherein a surface of the borehole within the underground reservoir of magma comprises hardened magma;wherein the wellbore comprises:a primary borehole with an opening at the surface and an end at a predetermined depth within the underground reservoir of magma; andat least one secondary borehole extending from the primary borehole within the underground reservoir of magma;wherein the heat transfer fluid comprises one or more of: water, a brine solution, one or more refrigerants, and one or more thermal oils;wherein the heat transfer fluid comprises one or more of a molten salt, an ionic liquid, and a nanofluid;wherein the fluid conduit is further coupled to a heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system;wherein at least a portion of the heat transfer fluid from the heat-driven process apparatus is returned to the wellbore; and/orwherein the fluid conduit comprises an insulation layer.

Embodiment 2. A method of operating a geothermal system, the method comprising:providing a heat transfer fluid down a wellbore extending from a surface and into an underground reservoir of magma;receiving heated heat transfer fluid from the wellbore; andproviding the heated heat transfer fluid to a heat-driven process, and wherein the method optionally includes any one or more following limitations:returning at least a portion of the heat transfer fluid from the heat-driven process back down the wellbore; and/orwherein:the heat transfer fluid provided down the wellbore comprises liquid water and the heated heat transfer fluid received from the wellbore comprises steam; andproviding the heated heat transfer fluid to the heat-driven process comprises:providing at least a portion of the steam to at least one turbine; andoperating the at least one turbine with the steam to generate electricity.

Embodiment 3. A geothermal system, comprising:a fluid pump configured to provide a flow of heat transfer fluid through a wellbore from a surface and toward an underground reservoir of magma; anda fluid conduit extending from the surface toward a terminal end of the wellbore located within a portion of the wellbore that extends into the underground reservoir of magma, the fluid conduit configured to allow flow of heated heat transfer fluid from the portion of the wellbore that extends into the underground reservoir of magma toward the surface, wherein the geothermal system optionally includes any one or more following limitations:wherein the fluid pump is configured to provide the flow of the heat transfer fluid through an annulus formed between a wall of the wellbore and an outer wall of the fluid conduit;wherein the fluid conduit comprises a drill stem positioned within the wellbore;wherein the heat transfer fluid comprises one or more of: water, a brine solution, one or more refrigerants, one or more thermal oils, a molten salt, an ionic liquid, and a nanofluid; and/orwherein the fluid conduit comprises an insulation layer.

Embodiment 4. A partially cased wellbore, the partially cased wellbore comprising:a first borehole portion extending from a surface towards an underground magma reservoir, the first borehole portion comprising a casing extending from a first end at the surface; anda second borehole portion extending from a terminal end of the first borehole portion to a terminal end of the wellbore, wherein the second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma, wherein the partially cased wellbore optionally includes any one or more following limitations:a fluid pathway extending from an inlet at the surface to the terminal end of the wellbore and then from the terminal end to an outlet at or above the surface, wherein the fluid pathway is configured to receive a heat transfer fluid at the inlet and expel heated heat transfer fluid from the outlet;wherein the fluid pathway comprises:an annular pathway formed in the first borehole portion between the casing and an external wall of a fluid conduit positioned within the partially cased wellbore;an annular pathway in the second borehole portion between the wall of the second borehole portion and the external wall of a fluid conduit; anda pathway within the fluid conduit;wherein the fluid conduit is a drill stem with a drill bit removed;wherein the fluid conduit comprises an insulation layer;wherein the casing comprises an alloy attached to an internal wall of the first borehole portion;at least one secondary borehole extending from the second borehole portion within the underground magma reservoir; and/ora plurality of secondary boreholes extending from the second borehole portion within the underground magma reservoir, wherein the plurality of secondary boreholes forms a network of boreholes with the underground magma reservoir.

Embodiment 5. A geothermal system, comprising:a partially cased wellbore;a fluid pump configured to provide a flow of heat transfer fluid through the partially cased wellbore from a surface and toward an underground magma reservoir; anda heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system, wherein the geothermal system optionally includes any one or more following limitations:wherein the partially cased wellbore comprises:a first borehole portion extending from the surface towards the underground magma reservoir, the first borehole portion comprising a casing extending from a first end at the surface; anda second borehole portion extending from a terminal end of the first borehole portion to a terminal end of the wellbore, wherein the second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma;wherein the partially cased wellbore further comprises a fluid pathway extending from an inlet at the surface to the terminal end of the wellbore and then from the terminal end to an outlet at or above the surface, wherein the fluid pathway is configured to receive a heat transfer fluid at the inlet and expel heated heat transfer fluid from the outlet;wherein the fluid pathway comprises:an annular pathway formed in the first borehole portion between the casing and an external wall of a fluid conduit positioned within the partially cased wellbore;an annular pathway in the second borehole portion between the wall of the second borehole portion and the external wall of a fluid conduit; anda pathway within the fluid conduit;wherein the fluid conduit is a drill stem with a drill bit removed;wherein the fluid conduit is a drill stem with a drill bit attached to the drill stem;wherein the fluid conduit comprises an insulation layer;wherein the casing comprises an alloy attached to an internal wall of the first borehole portion;wherein the partially cased wellbore further comprises at least one secondary borehole extending from the second borehole portion within the underground magma reservoir;wherein the partially cased wellbore further comprises a plurality of secondary boreholes extending from the second borehole portion within the underground magma reservoir, wherein the plurality of secondary boreholes form a network of boreholes with the underground magma reservoir;wherein the heat transfer fluid comprises one or more of: water, a brine solution, one or more refrigerants, and one or more thermal oils;wherein the heat transfer fluid comprises one or more of a molten salt, an ionic liquid, and a nanofluid; and/orwherein at least a portion of the heat transfer fluid from the heat-driven process apparatus is returned to the wellbore.

Embodiment 6. A method, comprising:supplying heat transfer fluid to a partially cased wellbore, the partially cased wellbore comprising:a first borehole portion extending from a surface towards an underground magma reservoir, the first borehole portion comprising a casing extending from a first end at the surface; anda second borehole portion extending from a terminal end of the first borehole portion to a terminal end of the wellbore, wherein the second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma;receiving heat transfer fluid heated in the partially cased wellbore; andproviding at least part of a gas-phase portion of the heated heat transfer fluid to a heat-driven process, wherein the method optionally includes any one or more following limitations:wherein providing at least part of the gas-phase portion of the heated heat transfer fluid to the heat-driven process comprises:providing at least part of the gas-phase portion of the heated heat transfer fluid to a turbine;operating the turbine with the gas-phase heat transfer fluid to generate electricity; anddirecting at least some condensed heat transfer fluid back to the partially cased wellbore.

Embodiment 7. A wellbore, the wellbore comprising:a borehole extending from a surface into an underground reservoir of magma;a chamber located within the borehole and extending at least partially into the underground reservoir of magma;an inlet conduit configured to allow flow of heat transfer fluid from the surface and into the chamber; andan outlet conduit configured to allow flow of heated heat transfer fluid from the chamber toward the surface, wherein the wellbore optionally includes any one or more following limitations:a valve configured to open to allow flow of the heated heat transfer fluid through the outlet conduit when a pressure in the chamber is at least a threshold value;wherein the outlet conduit comprises an insulation layer;wherein the outlet conduit is fluidly coupled to a heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system;wherein the chamber is in thermal contact with one or both of a wall of the borehole that extends into the underground reservoir of magma and a casing disposed on the wall;a thermally conductive layer contacting a wall of the chamber and one or both of the wall of the borehole that extends into the underground reservoir of magma and the casing disposed on the wall;wherein the heat transfer fluid comprises one or more of: water, a brine solution, one or more refrigerants, and one or more thermal oils; and/orwherein the heat transfer fluid comprises one or more of a molten salt, an ionic liquid, and a nanofluid.

Embodiment 8. A geothermal system comprising:a wellbore comprising:a borehole extending from a surface into an underground reservoir of magma, anda chamber located within the borehole and extending at least partially into the underground reservoir of magma; anda fluid pump configured to provide a flow of heat transfer fluid into the chamber, wherein the geothermal system optionally includes any one or more following limitations:wherein the wellbore further comprises:an inlet conduit configured to allow flow of heat transfer fluid from the surface and into the chamber; andan outlet conduit configured to allow flow of heated heat transfer fluid from the chamber toward the surface;a valve configured to open to allow flow of the heated heat transfer fluid through the outlet conduit when a pressure in the chamber is at least a threshold value;wherein the outlet conduit comprises an insulation layer;wherein the outlet conduit is fluidly coupled to a heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system;wherein the chamber is in thermal contact with one or both of a wall of the borehole that extends into the underground reservoir of magma and a casing disposed on the wall;a thermally conductive layer contacting a wall of the chamber and one or both of the wall of the borehole that extends into the underground reservoir of magma and the casing disposed on the wall;wherein the heat transfer fluid comprises one or more of: water, a brine solution, one or more refrigerants, and one or more thermal oils; and/orwherein the heat transfer fluid comprises one or more of a molten salt, an ionic liquid, and a nanofluid.

Embodiment 9. A method for generating power, the method comprising:supplying heat transfer fluid to a chamber positioned in a borehole extending at least partially into an underground reservoir of magma;receiving heat transfer fluid heated in the chamber;providing at least part of a gas-phase portion of the heated heat transfer fluid to at least one turbine;operating the at least one turbine with the gas-phase heat transfer fluid to generate electricity; anddirecting at least some condensed heat transfer fluid back to the chamber, wherein the method optionally includes any one or more following limitations:holding heat transfer fluid in the chamber until a pressure of the heat transfer fluid reaches at least a threshold value;wherein the heat transfer fluid is water and holding the heat transfer fluid in the chamber until the pressure of the heat transfer fluid reaches at least the threshold value comprises holding the water in the chamber until the water becomes steam at least at the threshold pressure; and/orwherein the chamber extends at least partially into the underground reservoir of magma.

Embodiment 10. A method of forming a wellbore extending from a surface into an underground reservoir of magma, the method comprising:drilling a primary borehole from the surface into the underground reservoir of magma; anddrilling a secondary borehole extending from the primary borehole and further into the underground reservoir of magma, wherein the method optionally includes any one or more following limitations:applying a casing to at least a portion of the primary borehole;wherein applying the casing comprises conveying a well casing into the primary borehole while or after advancing a drill bit used to drill the primary borehole towards the underground reservoir;wherein drilling the primary borehole comprises drilling in a first direction from the surface to a target depth;wherein drilling the secondary borehole comprises drilling further into the underground reservoir at an angle relative to the first direction;drilling an additional borehole extending from the secondary borehole;drilling a plurality of secondary boreholes extending from the primary borehole, each of the of the plurality of secondary boreholes extending in a different direction into the underground reservoir of magma; and/orproviding a flow of a cooling fluid into the secondary borehole during or after drilling of the secondary borehole to cause the magma in the underground reservoir to harden and form a wall of the secondary borehole.

Embodiment 11. A wellbore comprising:a primary borehole with an opening at a surface and an end at a predetermined depth within an underground reservoir of magma; andat least one secondary borehole extending from the primary borehole into the underground reservoir of magma, wherein the wellbore optionally includes any one or more following limitations:a casing applied to at least a portion of the primary borehole;wherein the at least one secondary borehole extends further into the underground reservoir at an angle relative to a first direction of the primary borehole;an additional borehole extending from the at least one secondary borehole;a plurality of secondary wellbores extending from the primary wellbore, each of the of the plurality of secondary wellbores extending in a different direction into the underground reservoir of magma; and/orwherein the secondary borehole comprises a wall formed of hardened magma.

Embodiment 12. A geothermal system, comprising:a wellbore comprising:a primary borehole with an opening at a surface and an end at a predetermined depth within an underground reservoir of magma; andat least one secondary borehole extending from the primary borehole into the underground reservoir of magma; anda fluid pump configured to provide a flow of heat transfer fluid into the wellbore, wherein the geothermal system optionally includes any one or more following limitations:a casing applied to at least a portion of the primary borehole;wherein the at least one secondary borehole extends further into the underground reservoir at an angle relative to a first direction of the primary borehole;an additional borehole extending from the at least one secondary borehole;a plurality of secondary wellbores extending from the primary wellbore, each of the of the plurality of secondary wellbores extending in a different direction into the underground reservoir of magma; and/orwherein the at least one secondary borehole comprises a wall formed of hardened magma.

Embodiment 13. A method, comprising:supplying water into a wellbore comprising:a primary borehole with an opening at a surface and an end at a predetermined depth within an underground reservoir of magma; andat least one secondary borehole extending from the primary borehole into the underground reservoir of magma;receiving a flow of steam from the wellbore;providing at least a portion of the received steam to at least one turbine;operating the at least one turbine with the steam to generate electricity; anddirecting at least some condensate during operation of the at least one turbine back to the wellbore.

Embodiment 14. A method of operating a geothermal system, the method comprising:providing a molten salt down a wellbore extending from a surface and into an underground reservoir of magma;receiving heated molten salt from the wellbore; andproviding the heated molten salt to a heat-driven process, wherein the method optionally includes any one or more following limitations:returning at least a portion of the molten salt from the heat-driven process back down the wellbore;providing the molten salt downward through an annulus formed between a wall of the wellbore and an outer wall of a fluid conduit configured to return the heated molten salt to the surface;wherein the fluid conduit comprises a drill stem positioned within the wellbore;wherein the wellbore comprises:a borehole with an opening at the surface and an end at a predetermined depth within the underground reservoir of magma; anda casing disposed within the borehole and extending from the surface until at least a ceiling of the underground reservoir of magma;wherein the casing extends into the underground reservoir of magma;wherein the casing extends no more than partially into the underground reservoir of magma, wherein a surface of the borehole within the underground reservoir of magma comprises hardened magma; and/orwherein the wellbore comprises:a primary borehole with an opening at the surface and an end at a predetermined depth within the underground reservoir of magma; andat least one secondary borehole extending from the primary borehole within the underground reservoir of magma.

Embodiment 15. A wellbore extending into an underground reservoir of magma, the wellbore comprising:a borehole with an opening at a surface and an end at a predetermined depth within the underground reservoir of magma; anda casing disposed within the borehole and extending from the surface until at least a ceiling of the underground reservoir of magma, wherein the wellbore optionally includes any one or more following limitations:wherein the borehole comprises:a first borehole portion extending from a surface towards the underground reservoir of magma, the first borehole portion comprising a casing extending from a first end at the surface; anda second borehole portion extending from a terminal end of the first borehole portion to a terminal end of the wellbore, wherein the second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma.wherein the wellbore further comprises:a chamber located within the borehole and extending at least partially into the underground reservoir of magma;an inlet conduit configured to allow flow of heat transfer fluid from the surface and into the chamber; andan outlet conduit configured to allow flow of heated heat transfer fluid from the chamber toward the surface;a valve configured to open to allow flow of the heated heat transfer fluid through the outlet conduit when a pressure in the chamber is at least a threshold value;wherein the outlet conduit comprises an insulation layer; and/orwherein the outlet conduit is fluidly coupled to a heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system.

Embodiment 16. A geothermal system comprising:a wellbore comprising:a borehole with an opening at a surface and an end at a predetermined depth within an underground reservoir of magma; anda casing disposed within the borehole and extending from the surface until at least a ceiling of the underground reservoir of magma; anda fluid pump configured to provide a flow of molten salt into the wellbore, wherein the geothermal system optionally includes any one or more following limitations:wherein the borehole comprises:a first borehole portion extending from a surface towards the underground reservoir of magma, the first borehole portion comprising a casing extending from a first end at the surface; anda second borehole portion extending from a terminal end of the first borehole portion to a terminal end of the wellbore, wherein the second borehole portion extends into the underground magma reservoir and a wall of the second borehole portion is hardened magma;wherein the wellbore further comprises:a chamber located within the borehole and extending at least partially into the underground reservoir of magma;an inlet conduit configured to allow flow of heat transfer fluid from the surface and into the chamber; andan outlet conduit configured to allow flow of heated heat transfer fluid from the chamber toward the surface;a valve configured to open to allow flow of the heated heat transfer fluid through the outlet conduit when a pressure in the chamber is at least a threshold value;wherein the outlet conduit comprises an insulation layer; and/orwherein the outlet conduit is fluidly coupled to a heat-driven process apparatus, wherein the heat-driven process apparatus comprises one or more of turbines, reaction vessels, condensers, a water distillation system, a heat driven chilling apparatus, a residential heating system, an agriculture system, and an aquaculture system.

Although embodiments of the disclosure have been described with reference to several elements, any element described in the embodiments described herein are exemplary and can be omitted, substituted, added, combined, or rearranged as applicable to form new embodiments. A skilled person, upon reading the present specification, would recognize that such additional embodiments are effectively disclosed herein. For example, where this disclosure describes characteristics, structure, size, shape, arrangement, or composition for an element or process for making or using an element or combination of elements, the characteristics, structure, size, shape, arrangement, or composition can also be incorporated into any other element or combination of elements, or process for making or using an element or combination of elements described herein to provide additional embodiments. Moreover, items shown or discussed as coupled or directly coupled or communicating with each other may be indirectly coupled or communicating through some interface device, or intermediate component whether electrically, mechanically, fluidically, or otherwise.

While this disclosure has been particularly shown and described with reference to preferred or example embodiments, it will be understood by those skilled in the art that various changes in form and detail may be made therein without departing from the spirit and scope of the disclosure. Accordingly, this disclosure includes all modifications and equivalents of the subject matter recited in the claims appended hereto as permitted by applicable law. Changes, substitutions and alterations are ascertainable by one skilled in the art and could be made without departing from the spirit and scope disclosed herein. Moreover, any combination of the above-described elements in all possible variations thereof is encompassed by the disclosure unless otherwise indicated herein or otherwise clearly contradicted by context.

Additionally, where an embodiment is described herein as comprising some element or group of elements, additional embodiments can consist essentially of or consist of the element or group of elements. Also, although the open-ended term “comprises” is generally used herein, additional embodiments can be formed by substituting the terms “consisting essentially of” or “consisting of.”