DRILLING EQUIPMENT POWERED BY GEOTHERMAL ENERGY

A drilling system includes a wellbore extending from a surface into a geothermal reservoir. The geothermal reservoir may be an underground magma reservoir. The wellbore is configured to heat a heat transfer fluid via heat transfer with the underground magma reservoir. A steam-powered motor uses the heat transfer fluid that is heated by the geothermal system to rotate a drill bit to drill a borehole.

TECHNICAL FIELD

The present disclosure relates generally to geothermal systems and related methods, and more particularly to drilling equipment powered by geothermal energy.

BACKGROUND

Holes are drilled into the Earth to access resources, such as oil, gas, water, or heat from below the Earth's surface. Considerable energy is expended to power the equipment used to perform such drilling. Renewable energy sources, such as solar power and wind power, can be unreliable and have relatively low power densities, such that they may be insufficient to reliably power drilling equipment. As such, drilling equipment typically relies on non-renewable fuels for power.

SUMMARY

This disclosure recognizes the previously unidentified and unmet need for a reliable renewable energy source for drilling equipment. This disclosure provides a solution to this unmet need in the form of drilling equipment that is powered at least partially by geothermal energy. A geothermal system harnesses heat from a geothermal resource with a sufficiently high temperature that can be used to power equipment used in drilling processes. For example, steam may be obtained from a geothermal system, and one or more steam-powered motors may be powered with the steam and used to support operations used to drill a borehole. For example, a steam-powered motor may cause rotation of a drill bit that is used to drill into the Earth. The same or a different steam-powered motor may move the drill bit downwards to facilitate the drilling process. Similarly, the same or a different steam-powered motor may power a pump that is used to cycle drilling fluid through the borehole being drilled. One or more turbines may be powered by the steam to provide electricity for any electronic components of the drilling equipment (e.g., electronic controllers, sensors, etc.).

In some embodiments, the geothermal system that powers the drilling equipment is a closed geothermal system that exchanges heat with a geothermal reservoir. The geothermal reservoir may be on the surface, such as lava, lava flow, or body of lava. The geothermal reservoir may be an underground geothermal reservoir. 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 an underground thermal reservoir, such as a magma. A closed heat-transfer loop is employed in which a heat transfer fluid is pumped into the wellbore, heated via contact with the underground thermal reservoir, and returned to the surface to power drilling equipment located within a sufficient proximity to the wellbore.

The geothermal system of this disclosure may harness 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 methods for capturing energy from magma reservoirs, dikes, 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. In some cases, the present disclosure can significantly decrease borehole production costs and/or reliance on non-renewable resources for drilling operations. In some cases, the present disclosure may facilitate more efficient drilling in regions where access to reliable power is currently unavailable or transport of non-renewable fuels is challenging. The systems and methods of the present disclosure may also or alternatively aid in decreasing carbon emissions.

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.

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. However, magma can be found at shallower depths in some cases. As used herein, “borehole” refers to, 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 some cases, the terms “wellbore” and “borehole” are used interchangeably. As used herein, “fluid conduit” refers to any structure, such as a pipe, tube, or the like, used to transport fluids. 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 involving heating or cooling.

FIG.1is a partial cross-sectional diagram100of 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, transitional region108, upper mantle110, and crust112. There are places on the Earth where magma reaches the surface of the crust112forming volcanoes114. 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 magma is desirable.

FIG.2illustrates a conventional geothermal system200that harnesses energy from heated ground water for power generation. The conventional 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 hydrothermal 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. Magma reservoir214can be any underground region containing magma such as a dike, sill, or the like. 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 the hydrothermal 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 the hydrothermal layer210via an injection well204.

The configuration of conventional geothermal system200ofFIG.2suffers from drawbacks and disadvantages, as recognized by this disclosure. For example, because geothermal water is a multicomponent mixture (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 causing 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 system300of this disclosure. The magma-based geothermal system300includes a wellbore302that extends from the surface216at least partially into the magma reservoir214. A heat exchanger306may be located inside the wellbore302. The magma-based geothermal system300is a closed system in which a heat transfer fluid is provided down the wellbore302to be heated and returned to a thermal 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 thermal process system304. The thermal process system304is generally any system that uses the heat transfer fluid to drive a process of interest. For example, the thermal process system304may include an electricity generation system and/or support thermal processes requiring higher temperatures/pressures than could be reliably or efficiently obtained using previous geothermal technology, such as the conventional geothermal system200ofFIG.2. Further details of components of an example thermal process system304are provided with respect toFIG.9below.

The magma-based geothermal system300provides technical advantages over previous geothermal systems, such as the conventional geothermal system200ofFIG.2. The magma-based geothermal system300can achieve higher temperatures and pressures for increased energy generation and/or for more effectively driving other thermal processes, such as for powering drilling operations, as described further below. For example, because of the high energy density of magma in magma reservoir214(e.g., compared to that of geothermal water of the hydrothermal layer210), wellbore302can generally create the power of many wells of the conventional geothermal system200ofFIG.2. Furthermore, the heat transfer fluid is generally not substantially released into the hydrothermal 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-based geothermal 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 thermal process system304because only relatively clean heat transfer fluid (e.g., steam) reaches the surface216. There may be no need or a reduced need to separate out solids or other impurities that are common to geothermal water. The example magma-based geothermal system300may include further components not illustrated inFIG.3.

Further details and examples of different configurations of geothermal systems and methods of their design, preparation, construction, and operation 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”; 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”; U.S. patent application Ser. No. 18/195,810, filed May 10, 2023, and titled “Reverse-Flow Magma-Based Geothermal Generation”, U.S. patent application Ser. No. 18/195,814, filed May 10, 2023, and titled “Partially Cased Wellbore in Magma Reservoir”; U.S. patent application Ser. No. 18/195,822, filed May 10, 2023, and titled “Geothermal System With a Pressurized Chamber in a Magma Wellbore”; U.S. patent application Ser. No. 18/195,828, filed May 10, 2023, and titled “Magma Wellbore With Directional Drilling”; U.S. patent application Ser. No. 18/195,837, filed May 10, 2023, and titled “Molten Salt as Heat Transfer Fluid in Magma Geothermal System”; and U.S. patent application Ser. No. 18/141,326, filed Feb. 28, 2023, and titled “Casing a Wellbore in Magma”, the entirety of each of which is hereby incorporated by reference.

In another embodiment of the present disclosure, the geothermal system300may be lava-based. For example, the geothermal system300may include a horizontal wellbore or a wellbore that extends a shorter distance from the surface216, such that the wellbore302extends from the surface216horizontally into the lava and/or from the surface216into a relatively shallow lava lake. The lava may be in a lava lake, lava flow, or other lava formation.

Example Geothermal-Powered Drilling System

FIG.4illustrates an example drilling system400of this disclosure. The drilling system400includes all or a portion of the components of the geothermal system300described above with respect toFIG.3as well as thermally powered drilling equipment500for preparing a borehole502. An example of the thermally powered drilling equipment500is described in greater detail below with respect toFIG.5. The drilling system400may include all or a portion of the thermal process system304. In operation, heated heat transfer fluid404a(e.g., steam) from the wellbore302flows to the thermal process system304and/or bypasses the thermal process system304as heat transfer fluid404b. The wellbore302extends from the surface216into the underground magma reservoir214. The heat transfer fluid406ais heated in the wellbore302via heat transfer with the underground magma reservoir214. Any remaining steam from the thermal process system304and/or the heat transfer fluid404bis provided as heat transfer fluid404cto the thermally powered drilling equipment500.

As described in greater detail below, the thermally powered drilling equipment500uses the heated heat transfer fluid404cat least in part to drill borehole502. For example, a motor of the thermally powered drilling equipment500may be powered by the heated heat transfer fluid404c, and the motor may provide motion to a drill bit, fluid pump(s), and/or the like of the thermally powered drilling equipment500(seeFIGS.5-8and corresponding description below). As another example, the thermally powered drilling equipment500may include a fluid pump with a motor that is powered at least in part by the heat transfer fluid404cthat was heated in the wellbore302. As another example, the thermally powered drilling equipment500may include a motor that aids in moving the rotating drill bit into the surface216and is powered at least in part by heat transfer fluid404cthat was heated in the wellbore302. More detailed examples of operations of thermally powered drilling equipment500are described below with respect toFIGS.5-8.

Heat transfer fluid406a(e.g., condensed steam) that is cooled and/or or decreased in pressure after powering the thermally powered drilling equipment500may be returned to the wellbore302. For instance, as shown in the example ofFIG.4, a stream of return heat transfer fluid406cmay be provided back to the thermal process system304, optionally used to drive one or more reactions or processes, and then expelled as heat transfer fluid406afor return to the wellbore302. The heat transfer fluid406acan also include a bypass stream of heat transfer fluid406b. Restated, thermally processed return stream of heat transfer fluid406aincludes heat transfer fluid (e.g., condensed steam) from the thermal process system304and/or the bypass stream of heat transfer fluid406b. Thermally processed return stream of heat transfer fluid406athat is sent back to the wellbore302may be water (or another heat transfer fluid), while the stream of heat transfer fluid404areceived from the wellbore302may be steam or another heat transfer fluid at an elevated temperature and/or pressure. While the example ofFIG.4includes the thermal process system304ofFIG.3, in some cases, the drilling system400may exclude all or a portion of the thermal process system304. For example, the wellbore stream of heat transfer fluid404afrom the wellbore302may be provided directly to the thermally powered drilling equipment500(see wellbore bypass stream of heat transfer fluid404bdescribed above).

Heat transfer fluid404a-c,406a-cmay be any appropriate fluid for absorbing heat within the wellbore302and driving operations of the thermally powered drilling equipment500and, optionally the thermal process system304. For example, the heat transfer fluid may 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). A molten salt is a salt that is a liquid at the high operating temperatures experienced in the wellbore302(e.g., at temperatures between 1,600 and 2,300° F.). In some cases, an ionic liquid may be used as the heat transfer fluid. 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 fluid. 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 wellbore302. For example, molten salts and/or ionic liquids may be stable at the high temperatures that can be reached in the wellbore302. 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. The heat transfer fluid may be selected at least in part to limit the extent of corrosion of surfaces of the drilling system400. As an example, the heat transfer fluid may be water. The water is supplied to the wellbore302as stream of heat transfer fluid406ain the liquid phase and is transformed into steam within the wellbore302. The steam is received as stream of heat transfer fluid404aand used to drive the thermally powered drilling equipment500.

Example Thermally Powered Drilling Equipment

FIG.5shows an example of the thermally powered drilling equipment500in greater detail. The configuration ofFIG.5is provided as an example only. The thermally powered drilling equipment500may include more or fewer components, and the components may be arranged in different configurations in order to drill the borehole502. The thermally powered drilling equipment500includes a derrick504, drill line506, hoisting equipment508, one or more thermally powered motors510, a traveling block512, a drive system514, a drill stem522, a drill bit524, a wellhead526, a drilling fluid tank528, a fluid pump532, and a separation device540.

The derrick504provides structural support for other components of the thermally powered drilling equipment500and facilitates the lowering and lifting of the drill bit524via these components. For example, the derrick504may be a supporting tower that holds other components of the thermally powered drilling equipment500. The derrick504may have any appropriate structure. The derrick includes a support block520that is a stationary support for a drill line506. The drill line506is a line that facilitates the transfer of motion from the hoisting equipment508to the traveling block512. The drill line506is coupled to the hoisting equipment508and the traveling block512. The hoisting equipment508includes a rotating surface that is in contact with the drill line506. Rotation of the surface causes movement of the traveling block512. The hoisting equipment508may be powered by the thermally powered motor(s)510, as described further below.

The traveling block512connects the drill line506to other components used to rotate the drill bit524(e.g., the drive system514and drill stem522), transport drilling fluid into and out of the borehole502, and the like. The traveling block512may include pulleys that facilitate motion of the traveling block512via motion imparted to the drill line506via hoisting equipment508. In the example ofFIG.5, the traveling block512is coupled to a drive system514. For example, movement of the traveling block512may be used to impart a downward movement516of the drill stem522and the drill bit524to facilitate creation of the borehole502. The drill stem522may include a drill pipe consisting of tool joints, a swivel, a bit, a drill string, drill collars, drives, subs, a top drive, shock absorbers, reamers and/or any other related equipment used during the drilling process.

The drive system514facilitates the rotational movement518of the drill stem522and thereby imparts a rotational force or torque to the drill bit524. The drive system may include a swivel, kelly drive, and turntable, as shown in the example ofFIG.5, or the drive system514may be a top drive or other appropriate equipment for generating the rotational movement518. The drive system514causes rotational movement518of the drill bit524. The drive system514may be powered at least in part by the thermally powered motor(s)510, as described further below.

The drill bit524can be any appropriate type of currently used or future-developed drill bit for forming the borehole502. For example, the drill bit524may be a tri-cone drill bit with an integrated underreamer (not shown) that projects radially outward to aid in positioning a casing (not shown for clarity and conciseness) within the borehole502. For example, an underreamer may be withdrawn or retracted to allow the drill bit524to be extracted from the borehole502without simultaneously extracting the well casing. One or more ejection nozzles (not shown for conciseness) may be positioned on the drill bit524and/or drill stem522to 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 borehole502.

The wellhead526includes fluid connections, valves, and the like for facilitating appropriate operation of the drilling system400. For example, the wellhead526may include one or more valves to control pressure within the borehole502. The wellhead526may include a relief valve for venting the borehole502if an excessive pressure is reached.

The fluid pump532facilitates flow of drilling fluid into the borehole502and flow536of drilling fluid out of the borehole502. The fluid pump532is any appropriate pump capable of pumping drilling fluid. Fluid tank528stores drilling fluid that is pumped through fluid conduit530. The fluid pump532provides fluid flow534through the conduit530. The drilling fluid aids in the drilling process and then returns with solids (e.g., cuttings from the borehole502) via flow536through return conduit538. The returned drilling fluid from conduit538is filtered by a separation device540before being returned to the fluid tank528. The separation device540removes at least a portion of the solids from the drilling fluid that is returned to the fluid tank528for reuse in the drilling process. The fluid pump532may be powered at least in part by the thermally powered motor(s)510, as described further below.

The one or more thermally powered motors510are powered at least in part by heat transfer fluid heated in the wellbore302(e.g., as heat transfer fluid406cofFIG.4). Cooled and/or condensed heat transfer fluid (e.g., water) may be provided back to the wellbore302as heat transfer fluid404c(see alsoFIGS.4,6, and7). A thermally powered motor510may use the heat transfer fluid heated in the geothermal wellbore302to rotate the drill bit524. For example, the thermally powered motor510may power the drive system514(described above). For example, a thermally powered motor510may be a steam-powered motor that uses steam from heat transfer fluid404cheated in wellbore302.

In some cases, a thermally powered motor510may use the heat transfer fluid heated by the geothermal wellbore302to move the rotating drill bit524into the surface216to form borehole502. For example, the thermally powered motor510may power the hoisting equipment508which is used move the drill line506and in turn impart downward movement516to the drill stem522and drill bit524. Other mechanisms for moving the drill bit524downwards may be used with a thermally powered motor510driving the downward motion.

In some cases, thermally powered motor510may use the heat transfer fluid heated by the geothermal wellbore302(heat transfer fluid406c) to power the fluid pump532, which provides a flow of drilling fluid into the borehole502being drilled by the drill bit524.

Examples of a thermally powered motors510are described below with respect toFIGS.6and7.FIG.6shows a thermally powered motor600which may be used as thermally powered motor510ofFIG.5. Thermally powered motor600includes a piston602within a cylinder604. One or more valves606control introduction of heat transfer fluid404c(e.g., steam) into the cylinder604, such that the piston602moves within the cylinder604. A rod608is connected to the piston602and to a flywheel610. Movement of the piston602within the cylinder604causes the flywheel610to rotate (movement612). The flywheel610is in turn coupled to the drill bit524, such that rotation of the flywheel610causes the drill bit524to rotate. This may be achieved, for example, by transferring energy614or motion from the flywheel610to the drive system514(seeFIG.5). The flywheel610may also or alternatively be coupled to the hoisting equipment514to move the drill bit524up and down (seeFIG.5). The flywheel610may also or alternatively be coupled to the fluid pump532to drive the flow of drilling fluid (seeFIG.5).

In the example ofFIG.6, the thermally powered motor600includes one or more turbines616that generate electricity using the heat transfer fluid heated by the wellbore302. For example, a portion618of heat transfer fluid404cmay be provided to the turbine(s)616to generate electricity. Condensed heat transfer fluid from the turbines(s)616is provided back to the wellbore302as a stream620which is included in heat transfer fluid406c. The turbine(s)616may be any known or yet to be developed turbine for electricity generation. In some cases, the electricity may be used to power electrical components622used by a drilling system (e.g., system400ofFIG.4). The electrical components622may include sensors, control devices, electronic valves, electronic switches, and the like. For example, the electrical components622may include temperature and pressure sensors used in the drilling system400, control devices used to interpret information from these sensors, and switches to adjust operation of the system400based on sensor data.

FIG.7shows another example thermally powered motor700, which may be used as motor510ofFIG.5. The example thermally powered motor700includes several of the same components illustrated inFIG.6and described above. However, the thermally powered motor700differs from thermally powered motor600by including an absorption chiller702and condenser708. The absorption chiller702receives a portion704of heat transfer fluid404cheated by the wellbore302. The portion704of heat transfer fluid404cis used by the absorption chiller702to cool a cooling fluid. A flow706aof cooled cooling fluid is provided to the condenser708. The condenser708transfers heat from stream710of heat transfer fluid404cfrom the valve(s)606to the flow706ain order to further cool and/or condense the heat transfer fluid406cthat is provided back to the wellbore302. A flow706bof heated cooling fluid is sent back to the absorption chiller702to be cooled. In some cases, a thermally powered motor510ofFIG.5may include both turbine(s)616ofFIG.6and an absorption chiller702ofFIG.7as well as other components not explicitly described.

Example Method of Operating a Thermally Powered Drilling System

FIG.8illustrates an example method800of operating the drilling system400ofFIG.4. The method800may begin at step802where the thermally powered motor510is powered by heat transfer fluid obtained from wellbore302, as described above with respect toFIGS.4-7. At step804, a borehole502is drilled using power (or force, motion, etc.) provided by the thermally powered motor510. At step806, heat transfer fluid is cooled and/or condensed and provided back to the wellbore302. Step806may be performed using the absorption chiller702described with respect toFIG.7above.

Modifications, omissions, or additions may be made to method800depicted inFIG.8. Method800may 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 thermally powered drilling system400being used to perform steps, any suitable component(s) may perform or may be used to perform one or more steps of the method800.

Example Thermal Processing Subsystem

FIG.9shows a schematic diagram of an example thermal process system304ofFIGS.3and4. The thermal process system304includes a steam separator902, a first turbine set904, a second turbine set908, a high-temperature/pressure thermochemical process912, a medium-temperature/pressure thermochemical process914, and one or more lower temperature/pressure processes916a,b. The thermal process system304may include more or fewer components than are shown in the example ofFIG.9. For example, a thermal process system304used for power generation alone may omit the high-temperature/pressure thermochemical process912, medium-temperature/pressure thermochemical process914, and lower temperature/pressure processes916a,b. Similarly, a thermal process system304that is not used for power generation may omit the turbine sets904,908. As a further example, if heat transfer fluid is known to be received only in the gas phase, the steam separator902may be omitted in some cases. The ability to tune the properties of the heat transfer fluid received from the unique wellbore302ofFIGS.3and4facilitates improved and more flexible operation of the thermal process system304. For example, the depth of the wellbore302, the residence time of heat transfer fluid in the magma reservoir214, the pressure achieved in the wellbore302, and the like can be selected or adjusted to provide desired heat transfer fluid properties at the thermal process system304.

In the example ofFIG.9, the steam separator902is connected to the wellbore302that extends between a surface and the underground magma reservoir. The steam separator902separates a vapor-phase heat transfer fluid (e.g., steam) from liquid-phase heat transfer fluid (e.g., condensate formed from the vapor-phase heat transfer fluid). A stream920received from the wellbore302may be provided to the steam separator902. In some cases, all of stream918is provided in stream920. In other cases, a fraction or none of stream918is provided to the steam separator902. Instead, all or a portion of the stream918may be provided as stream928which may be provided to the first turbine set904and/or to a high-pressure thermal process912in stream929. The thermal process912may 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), such as the thermally powered drilling equipment500. One or more valves (not shown for conciseness) may be used to control the direction of stream920to the steam separator902, first turbine set904, and/or thermal process912. A vapor-phase stream922of heat transfer fluid from the steam separator902may be sent to the first turbine set904and/or the thermal process912via stream926. A liquid-phase stream924of heat transfer fluid from the steam separator902may be provided back to the wellbore302and/or to condenser942. The condenser942is any appropriate type of condenser capable of condensing a vapor-phase fluid. The condenser942may be coupled to a cooling or refrigeration unit, such as a cooling tower (not shown for conciseness).

The first turbine set904includes one or more turbines906a,b. In the example ofFIG.9, the first turbine set includes two turbines906a,b. However, the first turbine set904can include any appropriate number of turbines for a given need. The turbines906a,bmay be any known or yet to be developed turbine for electricity generation. The first turbine set904is connected to the steam separator902and is configured to generate electricity from the vapor-phase heat transfer fluid (e.g., steam) received from the steam separator902(vapor-phase stream922). A stream930exits the first turbine set904. The stream930may be provided to the condenser942and then back to the wellbore302. The condenser942may be cooled using a heat driven chiller, such as the absorption chiller702ofFIG.7.

If the heat transfer fluid is at a sufficiently high temperature, as may be uniquely and more efficiently possible using the wellbore302, a stream932of vapor-phase heat transfer fluid may exit the first turbine set904. Stream932may be provided to the second turbine set908to generate additional electricity. The turbines910a,bof the second turbine set908may be the same as or similar to turbines906a,b, described above.

All or a portion of stream932may be sent as vapor-phase stream934to a thermal process914. Process914is generally a process requiring vapor-phase heat transfer fluid at or near the conditions of the heat transfer fluid exiting the first turbine set904. For example, the thermal process914may include one or more thermochemical processes requiring steam or another heat transfer fluid at or near the temperature and pressure of stream932(e.g., temperatures of between 250 and 1,500° F. and/or pressures of between 500 and 2,000 psig). The second turbine set908may be referred to as “low pressure turbines” because they operate at a lower pressure than the first turbine set904. Fluid from the second turbine set908is provided to the condenser942via stream936to be condensed and then sent back to the wellbore302via stream936.

An effluent stream938from the second turbine set908may be provided to one or more thermal processes916a,b. Thermal processes916a,bgenerally require less thermal energy than thermal processes912and914, described above (e.g., processes916a,bmay be performed temperatures of between 220 and 700° F. and/or pressures of between 15 and 120 psig). As an example, processes916a,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 process916amay 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 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. An effluent stream940from all processes912,914,916a,b, may be provided back to the wellbore302. This disclosure describes example systems that may facilitate improved and/or more efficient drilling using geothermal energy. While these example systems are 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.3and4may 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 this disclosure.

Embodiment 1. A drilling system, comprising:a geothermal system comprising a wellbore extending from a surface into an underground magma reservoir, the wellbore configured to heat a heat transfer fluid via heat transfer with the underground magma reservoir;a drill rig comprising:a drill bit; anda steam-powered motor configured to use the heat transfer fluid heated by the geothermal system to rotate the drill bit, and optionally one or more of the following features:wherein the steam-powered motor is further configured to use the heat transfer fluid heated by the geothermal system to move the rotating drill bit into the surface;wherein the steam-powered motor is further configured to use the heat transfer fluid heated by the geothermal system to drive a pump configured to provide a flow of drilling fluid into a borehole drilled by the drill bit;wherein the steam-powered motor comprises:a piston within a cylinder;one or more valves configured to control introduction of steam into the cylinder, such that the piston moves within the cylinder; anda rod connected to the piston and to a flywheel, wherein movement of the piston within the cylinder causes the flywheel to rotate, wherein the flywheel is coupled to the drill bit, such that rotation of the flywheel causes the drill bit to rotate;the system further comprising:an absorption chiller configured to:receive heat transfer fluid heated by the geothermal system; andgenerate a cooling fluid using the received heat transfer fluid; anda condenser configured to:receive the cooling fluid; andcondense the heat transfer fluid via heat transfer with the received cooling fluid before the heat transfer fluid is returned to the wellbore of the geothermal system;the system further comprising one or more turbines configured to generate electricity using the heat transfer fluid heated by the geothermal system; and/orwherein the heat transfer fluid comprises water.

Embodiment 2. A 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; andpowering drilling equipment using the heated heat transfer fluid to drill a borehole, andoptionally one or more of the following features:wherein powering the drilling equipment comprises:causing a steam-powered motor to rotate;causing a drill bit coupled to the steam-powered motor to rotate; andcause the rotating frill bit to move into the surface;wherein powering the drilling equipment comprises:using the heat transfer fluid heated by the geothermal system to drive a pump; andproviding, using the pump, a flow of drilling fluid into the borehole drilled by the drill bit;wherein the steam-powered motor comprises:a piston within a cylinder;one or more valves configured to control introduction of steam into the cylinder, such that the piston moves within the cylinder; anda rod connected to the piston and to a flywheel, wherein movement of the piston within the cylinder causes the flywheel to rotate, wherein the flywheel is coupled to the drill bit, such that rotation of the flywheel causes the drill bit to rotate;the method further comprising:receiving, by an absorption chiller, the heat transfer fluid heated by the geothermal system;generating, by the absorption chiller, a cooling fluid using the received heat transfer fluid;receiving, by a condenser, the cooling fluid; andcondensing, by the condenser, the heat transfer fluid via heat transfer with the received cooling fluid before the heat transfer fluid is returned to the wellbore of the geothermal system;the method further comprising:generating electricity using the heat transfer fluid heated by the geothermal system; andusing at least a portion of the generated electricity for powering the drilling equipment; and/orwherein the heat transfer fluid comprises water and the heated heat transfer fluid comprises steam.

Embodiment 3. A steam-powered motor comprising:a piston within a cylinder;one or more valves configured to:receive steam heated in a wellbore extending from a surface into an underground magma reservoir; andcontrol introduction of steam into the cylinder, such that the piston moves within the cylinder; anda rod connected to the piston and to a flywheel, wherein movement of the piston within the cylinder causes the flywheel to rotate.

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.”