Methods of extracting thermal energy from a rock formation, completing geothermal production wells, drilling deep well holes, developing a high temperature hot dry rock geothermal reservoir, developing geothermal reservoirs in hot dry rock formations , completing geothermal production wells, generating geothermal production wells and processing chemical reactions

Abstract

METHODS OF EXTRACTING THERMAL ENERGY FROM A ROCK FORMATION, OF COMPLETING GEOTHERMAL PRODUCTION WELLS, OF DRILLING DEEP WELL HOLES, OF DEVELOPING A GEOTHERMAL RESERVOIR OF A ROTARY HYDROMATIC HYDROMATIC RESOURCES. , TO COMPLETE GEOTHERMAL PRODUCTION WELLS, TO GENERATE GEOTHERMAL PRODUCTION WELLS AND TO PROCESS CHEMICAL REACTIONS The present invention relates to a method and system for extracting and / or using thermal energy from rock formations. This summary is provided to comply with the rules that require a summary that allows a researcher or other reader to ascertain the topic of technical dissemination. This summary is presented with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

Description

"METHODS OF EXTRACTING THERMAL ENERGY FROM A ROCK FORMATION, OF COMPLETING GEOTHERMAL PRODUCTION WELLS, OF DRILLING DEEP WELL HOLES, OF DEVELOPING A HIGH-TEMPERATURE HOT DRY ROCK GEOTHERMAL RESERVOIR, OF DEVELOPING GEOTHERMAL RESERVOIRS IN HOT DRY ROCK FORMATIONS, OF COMPLETING GEOTHERMAL PRODUCTION WELLS, OF GENERATING GEOTHERMAL PRODUCTION WELLS AND OF PROCESSING CHEMICAL REACTIONS" CROSS-REFERENCE TO RELATED REQUESTS This application claims priority to, and incorporates by reference all disclosures of U.S. Provisional Patent Application No. 60 / 582,626, filed June 23, 2004, and U.S. Provisional Patent Application No. 60 / 650,667, filed February 7, 2005. BASIS OF THE INVENTION Field of Invention The present invention relates to well drilling, well completion methods, and the extraction and / or utilization of thermal energy from rock formations below the earth's surface. History of Related Technique Permeable geological strata with high temperatures are found in numerous locations around the globe. When meteoric water percolates into these formations, the water is heated and can flow to the surface as geysers and hot springs. Impermeable rock formations, typically Precambrian rocks, which have high temperatures are found almost everywhere around the globe and are generally located at greater depths than permeable geological strata with high temperatures, which are typically sedimentary rock in nature. These Precambrian formations... Impermeable Cambrian rocks are generally considered dry, and heat can be recovered from these formations through the hot dry rock (HDR) geothermal production process, in which water is pumped down a borehole into these deep, hot, impermeable rock formations and heated by contact with the rock. If the rock in its natural state does not have a sufficient network of cracks and fissures for water to flow through to capture heat, as is usually the case, the rock is hydraulically fractured to produce such a fracture network by means of fluid pressure. Several devices have been established to continuously circulate heat from these HDR formations. Today, energy is primarily supplied through fossil fuels such as coal, oil, and gas. These resources are finite and are therefore expected to be in short supply in the foreseeable future. The use of fossil fuels also appears to cause serious environmental problems. Furthermore, the US currently imports a large percentage of its oil. Dependence on foreign oil is increasing while domestic reserves are dwindling. Thus, the development of alternative energy sources is necessary. When coal is burned, significant amounts of sulfur and nitrogen oxides are released into the atmosphere. These gases combine with water in the atmosphere to produce acids that are carried to land by rain and wind from the source of emissions. This “acid rain” has a detrimental effect on aquatic and plant life.On a simple long-term scale, the atmosphere may be warming due to the greenhouse effect, which can be caused by large amounts of carbon dioxide being released into the atmosphere as a result of burning fossil fuels. The long-term consequences of the greenhouse effect are currently a topic of debate. They may include the melting of polar ice caps, with the resulting rise in sea level and flooding. Coastal cities and increased desertification of the planet. Evidence pointing towards warming due to the greenhouse effect includes increases in atmospheric carbon dioxide levels during the last century and climate records that seem to indicate an upward trend in atmospheric temperatures. These facts point to the need to consider mitigating action now, before we are overwhelmed by our own emissions. Hydropower, the world's first primary source of non-fossil energy, is both economical and clean. Hydropower has been widely developed in many parts of the world, but it will never fulfill more than a small fraction of the world's total energy needs. Other alternative energy sources are nuclear fission, solar, wind fusion, and geothermal. Nuclear fission is already widely used, but it is currently suffering from a lack of public confidence, particularly in the United States, as a result of common knowledge of incidents such as Three Mile Island and Chernobyl. There are few nuclear power plants currently in the planning or construction stages. Solar energy has been demonstrated on a small scale, as has wind energy. Although both of these sources are renewable energy, they are subject to variations in local weather conditions and can only be configured to distribute energy intermittently.Nuclear fusion is potentially a nearly limitless source of energy, relying on hydrogen isotopes for fuel, which are found in abundant quantities in seawater. However, unambiguous fusion has only been demonstrated in the highly rebellious form of a thermonuclear explosion. It may be decades before the burning and containment of a fusion reaction using non-nuclear ignition sources, such as lasers, are developed to the point where nuclear fusion can find practical application as an energy source. Geothermal resources in the form of fluid systems Naturally occurring hydrothermal resources are being exploited today to provide useful energy such as electricity or heat in various parts of the world. Currently, hydrothermal resources provide only a tiny fraction of the world's energy needs, although the potential resource base available for exploitation is of the same order of magnitude as fossil fuel sources. Hydrothermal resources remain much cleaner than fossil fuels with respect to greenhouse gas emissions, generally releasing only about 10% or less of the amount of carbon dioxide produced by burning an equivalent amount of fossil fuel energy. However, hydrothermal resources are geographically limited, occurring primarily in areas of tectonic or volcanic activity. Thus, many densely populated parts of the world are poorly located for hydrothermal vent exploitation. Hot dry rocks (HDRs), typically Precambrian rocks, underlie much of the globe. Unlike hydrothermal resources, HDRs are widely distributed around the earth, generally underlying sedimentary-based hydrothermal formations. The potential of HDR resources is of great magnitude and, like fusion, HDRs can provide a nearly limitless source of energy for the planet. Hydrothermal plants now in operation conclusively demonstrate that the earth's heat can be utilized as a practical source of both thermal and electrical energy. The HDR process is a logical extension of hydrothermal technology to fit into a vastly larger and universally distributed energy resource. The conventional approach to extracting energy from HDR involves creating a closed-loop liquid circulation system consisting of an HDR reservoir and above-ground equipment. Initially, an injection well is drilled into the hot, dry rock and fracturing techniques are employed. Hydraulic fracturing is used to induce permeability by stimulating existing natural joints or creating new fractures. Hydraulic stimulation and fracturing are widely used in oil recovery. An HDR reservoir is thus created, the size of which is governed by the pressure, velocity, and volume of the hydraulic fracturing fluid applied to the rock, the nature of the rock structure, and in-situ stresses, as has been clearly demonstrated in modern HDR completions, such as that cited in the Geodynamics Limited Quarterly Report for the period ending March 31, 2004. Additional wells are then drilled to provide the remainder of the fluid circuits needed to establish the closed-loop circulation system.For heat production, liquid is pumped down into the injection well, heated by the hot rock of the HDR reservoir, and recovered from a second well, a production well drilled into the reservoir some distance from the injection well. Several injection and recovery wells can be used within the basic closed-loop circulation system. Surface heat exchangers are used to recover heat from the water for use in electricity generation or for direct thermal applications. The water is then reinjected into the HDR reservoir through the injection well. In this way, heat can be continuously “mined” from otherwise inaccessible geothermal sources. Essentially, there is no discharge of gases or saline fluids into the environment.Thus, the HDR process does not emit carbon dioxide or precursors to acid rain, such as sulfur dioxide, and is in the same category as solar, wind, or hydroelectric power, being an environmentally benign source of energy. The primary application of heated water in HDR reservoirs will be to generate steam or vaporize another working fluid such as ammonia or isobutane for use in the production of electrical energy. US Patent 3,786,858, issued January 22, 1974, This describes the HDR process. A publication issued by Los Alamos National Laboratory in July 1989, designated LA-11514-MS and titled “Hot Dry Rock Geothermal Energy: A New Energy Agenda for the 21st Century,” describes a number of concepts for HDR energy utilization. There are experimental HDR sites in Europe, Japan, and the United States, and commercial HDR initiatives are under development in Europe and Australia. The Geothermal Resources Council periodically publishes a bulletin dealing with geothermal energy issues. SPE document No. 30,738, titled “Hot Dry Rock: A Versatile Alternative Energy Technology,” by D.V. Duchane, Earth and Environmental Sciences Division, Los Alamos National Laboratory, presented in October 1995, describes the current state of HDR development. The public offering prospectus offered by Geodynamics Limited of Australia, entitled “Geodynamics Limited - ABN 55 095 006 090 - Power from the Earth - Prospectus” dated August 13, 2002, provides the most modern process envisioned and effort to develop and commercialize an HDR power generation system. The Geodynamics HDR model provides multiple lenses of open natural rock joint groups to be vertically interconnected through common injection and production wellbores to provide the base from which to heat mine from a “triptych” of wells. Heat is mined from the reservoir rock through continuous circulation from an injection well to multiple production wells, which provide a pressure source to induce directional circulation. This commonly known configuration provides a closed-loop, point-specific, directionally pressure-sink type circulation system. Companies that supply electricity must have sufficient power generation capacity not only to meet basic load demand, but also to meet peak or temporary demand. Peak demand, which usually occurs in the late afternoon of a hot summer day. Power generation equipment that is in reserve must be able to be brought online very quickly to prevent blackouts or load shedding. Load shedding refers to cutting off power to some users to prevent a catastrophic shutdown of the entire system. Such equipment is commonly referred to as "spinning reserve." Spinning reserve power or peak power is expensive, since the equipment used to generate spinning reserve power is only in use for payoff generation a portion of the time instead of 24 hours a day. Also, the equipment is generally more expensive to buy and operate than baseload power generation equipment. US Patent 5,685,362, issued November 11, 1997, describes a method of achieving peak energy demands with an HDR heat mining system and a power generation plant. Thus, invention 5,685,362 utilizes an HDR power generation system to follow electrical load. Invention 5,685,362 can also be termed on-demand peak energy. Peak energy from an HDR system could be cheaper to generate than peak energy from other sources and could still be sold at the same price as peak energy generated by other devices such as a gas turbine. Using an HDR system in a load-following mode instead of just to provide base load power will reduce the total operating cost of an HDR system. The incremental equipment cost for operating in peak mode is expected to be modest.This process is described in an undated document entitled “The Geothermal Analog of Pumped Storage for Electrical Demand Load Following” by Donald W. Brown, Los Alamos National Laboratories, Earth and Science Division, Los Alamos, New Mexico 87545. Invention 5,685,362 teaches the practice of heat mining by means of continuous fluid circulation through an injection well and... Several production wells coupled with the method of periodic reduction of production well backpressure to allow the short-term flow of a volume greater than the steady-state flow volume to be produced, thereby providing periodic peak energy capacity to provide load-following characteristics for electricity generation. The gasification of organic material under supercritical water conditions, as taught by Modell et al. in U.S. Patent 4,113,446 issued September 12, 1978, entitled "Gasification Process," is known in the art. Also, the use of an underground borehole to provide a gravity-based reactor vessel from which to carry out continuous supercritical chemical reactions in water, as taught by Titmus in U.S. Patent 4,594,164 issued June 10, 1986, entitled "Method and Apparatus for Conducting Chemical Reactions at Supercritical Conditions," is an example of the prior art and is also known. These teachings provide a process for converting organic material by means of aerobic supercritical water gasification.Oil and gas resources are a finite resource whose production capacity is rapidly declining, and it is therefore essential that the organic carbon found in coal, which is found in large quantities on a global basis, be made useful through the ability to convert coal into clean-burning combustible gases and liquids while capturing the various other marketable or harmful constituents for useful sale or disposal as the case may be. The HDR concept of generating geothermal heat has been known for several decades and has generally been relegated to a non-commercial technology due to the highly prohibitive cost of drilling numerous wells in the deeply buried Precambrian hot dry rock formations of the crystalline type. Modern attempts to commercialize the method HDR (High-Resolution Geothermal) developments must locate a very unique set of conditions in geological areas that exhibit exceptionally high geothermal gradients to provide manageable project drilling costs at relatively shallow drilling depths. Typically, these developments seek a site with significant sediment loading before drilling into Precambrian formations to access HDR, thus minimizing drilling costs by drilling a minimum section of the wellbore in Precambrian-type rock. Furthermore, these modern attempts to commercialize HDR geothermal production are economically constrained by the high cost of drilling injection wells and multiple production wells. The high cost of wellbore construction severely limits the design from being engineered as a production system optimized to exploit the maximum available heat in the source rock. The present invention provides a method of drilling, completing, and producing a geothermal reservoir to: a) economically locate said geothermal reservoirs in most areas of the world, even those areas with lower thermal gradients that are currently uneconomical to produce; b) economically locate said geothermal reservoirs at depths that provide supercritical water conditions; c) maximize the effective geothermal heat recovery per unit volume of HDR formation; and d) provide a method of producing and utilizing said geothermal heat energy for individual or simultaneous direct and / or indirect applications such as any individual generation or combination of generation and utilization of high-temperature geothermal process steam.The generation and use of geothermal heat energy for electricity production and / or the generation and use of geothermal heat energy in the processing of organic carbon or other chemical reactions. SUMMARY OF THE INVENTION The present invention relates to a method of drilling, completing and producing a deep geothermal reservoir to enable the economical extraction of thermal energy from geological strata that can be termed as hot dry rock (HDR). In one configuration, the present invention relates to a method of economically drilling deep well holes in Precambrian and / or Hadean-era crystalline rock, such as granites, basalts, and the like, which are typical of HDR formations. The cost of drilling well holes in HDR using current rotary mechanical drilling methods has virtually eliminated the opportunity to tap into the vast HDR potential. The innovative application of using a predominantly hydraulically based drilling method to overcome the inherent disadvantages of the rotary mechanical system, such as slow penetration speed and deformed hole tendencies, will provide an economical device to tap into the vast HDR potential. Specifically, the use of hydraulic drilling methods, Particle Jet Drilling (PJD), is considered to overcome the disadvantages of rotary mechanical drilling.A key advantage of certain configurations of the present invention includes combining the use of PJDs from deep wellbore holes terminating in HDR formations. This should sufficiently reduce the cost of accessing the higher temperature HDR depths, while providing the highest possible energy density output for the economical exploitation of the vast HDR source. In another embodiment, the present invention relates to a method of developing a high-temperature HDR geothermal reservoir to supply geothermal heat energy for applications such as electricity generation, including baseload and load following capacities, and the processing of various organic materials to produce Products marketed include clean-burning combustible gases and liquids, purified liquids, processed organic waste materials, and other chemical reactions. In another aspect, an embodiment of the present invention relates to a system that provides sequential loading and unloading of the HDR reservoir from one or more groups of vertically or horizontally separated dilated rock joints, or reservoirs. This aspect of the invention provides the ability to produce significantly larger volumes of heat energy from each fracture HDR reservoir system when compared with the conventional method of producing heat energy from a fracture HDR reservoir system. Additionally, this method of producing an HDR reservoir system provides an increase in HDR reservoir productivity over time due to the reservoir amplification effects of simultaneous mechanical and thermal pressure cycling of the reservoir system when compared with the conventional method of producing an HDR reservoir. In another aspect, an embodiment of the present invention relates to a method of extracting thermal energy from a rock formation. The method comprises the steps of drilling a plurality of wells to a sufficient depth to permit the development of at least one reservoir comprising a fracture joint mist, hydraulically fracturing at least one of the plurality of portions by expanding at least one fracture joint mist reservoir, forcing cooled fluid under high pressure and volume into at least one of the plurality of wells, alternately opening and closing a plurality of discharge control valves and a plurality of injection control valves to provide flow, either periodic or continuous, from the plurality of wells, removing heated fluid from the wells and / or passing the heated fluid to a heat exchanger, or using the produced fluid for other applications. direct. In another aspect, configurations of the invention provide a method of reducing the high cost of drilling deep wells terminating in crystalline rock in the Precambrian or Hadean Era, which are well known in the oil and gas and geothermal industries. The cost of drilling these wells in Precambrian or Hadean rock is a significant part of the cost that limits the depth, diameter, and number of wells that can be used to economically exploit HDR geothermal resources. The first part of the invented method for producing globally dispersed geothermal resources is the significant reduction of drilling costs associated with drilling deep wells terminating in Precambrian or Hadean rock for the purpose of developing engineered HDR reservoirs.Significant drilling cost reduction is achieved by using particle jet drilling (PJD) methods to drill the wellbore required to access, generate, and produce HDR reservoirs. The experimental use of jetted particles designed to drill oil and gas wells has been well documented by the oil and gas industry. There are primarily two forms of drilling processes that incorporate high-mass particles entrained in the drilling fluid. The use of high-mass particles entrained in drilling fluid was demonstrated by Gulf Oil Company in early 1969 based on US Patent 3,348,189 issued on May 21, 1968, and the more recent use of larger-diameter high-mass particles entrained in drilling fluid was patented by the inventor as US Patent 6,386,300 issued on May 14, 2002. These references focus particularly on the use of particle jet-assisted rotary mechanical drilling (PJARMD). The referenced methods of drilling deep wells with PJARMD constitute the entrainment process. Discrete solid particles of high density in the drilling fluid cut the formation using the momentum energy imparted to the rock by the quantity of motion transmitted from the high-mass particles to generically cut, slice, fracture, crack, displace, or fail the formation and remove the formation at a rapid rate. PJARMD processes have been successfully demonstrated in laboratory tests to increase the drilling speed of various land formations. Certain experimental PJARMD field tests have been conducted in conjunction with oil and / or gas well drilling in sedimentary formations. A fully hydraulic particle jet drilling (HPJD) method for drilling crystalline rocks has also been tested in the laboratory and in the field.The application of PJARMD and HPJD to reduce the cost of wells terminating in Precambrian or Hadean formations is fundamental to the widespread development of HDR potential. Specifically, PJD provides a means of economically drilling very deep, large-diameter wells for injection and production purposes for HDR production. The use of both PJD methods in conjunction with specialized completion and further production methods described herein will collectively serve to generate widespread development and utilization of HDR geothermal energy. Cost-effective geothermal well drilling provides the ability to locate cost-effective HDR geothermal energy production close to existing end users to displace fossil fuel use, especially when the end-user application is situated in a low thermal gradient location. The ability to hydraulically dilate existing natural joints in crystalline rock at depth to form a pressure-dilated joint permeability network in which fluids can be circulated is well documented in the HDR literature. The method of heat mining HDR by means of continuous circulation between several wells that are arranged to create a directionally specific pressure dissipator-type flow path point to point through a mist of expanded joints or fractures that are artificially generated by means of hydraulic fracturing of the normally impermeable HDR formation is well documented in the generic HDR literature. The present invention relates to the method of producing from an HDR fracture mist system by alternating the hydraulic expansion and contraction of the fracture mist system, in such a way as to generate coincident or sequenced thermal and mechanical cycling of the HDR formation to generate periodic or continuous surface cracking of near fracture within the HDR formation.This fracturing serves the purpose of incrementally exposing new high differential thermal surfaces on an incremental base that will provide the means to maintain high temperature production, plow the HDR formation of heat more effectively through incremental surface exposure, and generate an increased reservoir capacity over time through formation fracturing, which will increase the surface area being swept over time. Configurations of the present invention are further related to generating a reservoir production method that eliminates the point-to-point directionally specific pressure source flow path of the commonly known conventional HDR production system. The present invention utilizes hydraulic pressurization of the reservoir on a per-cycle basis to inject fluid into all areas of the reservoir. This loading action stores elastic deformation energy in the HDR formation. The reservoir is then allowed to produce a fluid injected to one or more production wells within the reservoir through the contraction of the reservoir volume due to the relaxation of the elastic deformation energy stored in the reservoir rock. The distributive flow paths and Recovery through the joint system generated by this type of production method is omnidirectional during both the injection and production cycles. This has the effect of substantially increasing the surface area swept by the working fluid, as opposed to the commonly known methods of directionally specific flow paths from point-to-point pressure sinks used in current HDR production methods. Configurations of the present invention further relate to the step of developing one or more discrete reservoirs by dilating a group of joints to form said reservoir. This reservoir is then alternately loaded and unloaded with a fluid to dilate the reservoir and cause the fluid to pass into and then out of the reservoir. This method is expected to force the fluid to sweep the dilated joint surface in two directions, thus providing a longer duration for the fluid to be able to absorb heat from the rock. The cyclic induction of simultaneous mechanical and thermal stress reversals on the reservoir rock face stresses the crystalline rock at or near the reservoir rock face and causes the reservoir rock face to continuously crack or fragment, exposing new reservoir rock surface.This type of fracturing is called shear bonding and generates a network of cross fractures on the surface of the larger fracture surface that is having its heat swept away. This shear bond fracturing can form cracked or fractured rock fragments ranging in size from very small to very large, depending on several variables. This type of active fracturing continuously provides newly exposed reservoir surface area that will promote greater heat transfer due to incremental exposure of the rock mass to the heat-sweeping water. Furthermore, the fracturing process will always provide a surface area... increasing the degree from which heat is swept away, and therefore an increased capacity to produce heat over time. This cyclic method of multiple stress inversions results in a continuous and incremental increase in the exposed high differential thermal surface area and an increase in reservoir volume. The rock formation being broken up by these cyclic stress inversions is expected to provide the capacity to continuously sweep heat from the rock formation in a way that allows for increased yield in removing a greater amount of available heat density per unit volume than with conventional HDR production methods.Additionally, this reservoir production method provides little or no water loss as typically characterized by a directionally specific, point-to-point pressure sink flow path circulating in a closed loop through two or more wells as practiced by previous hot dry rock production methods. These conventional HDR production methods with directionally specific, point-to-point pressure sink flow paths tend to hydraulically isolate large portions of the reservoir that may not be produced using conventional HDR production methods. The production method of the present invention provides near-complete flow recovery in each pressure cycle of the reservoir volume loaded to a central production point due to the omnidirectional flow and fluid return loading paths.When the reservoir of the present invention matures, cross-circulation of fluid is expected to occur within the reservoir, which will assist in recovering convective heat from the reservoir. Reservoir systems can be a) a single discrete reservoir that is independently circulated to produce a cyclical or periodic output, b) a set of several independent reservoirs that can be circulated and sequenced to produce a flow of continuous production that can be fluctuating and / or steady-state for purposes such as load tracking and / or c) a single reservoir that has several wells that can serve the purpose of simultaneous injection and production in a way that the injection wells inject periodically at a rate that exceeds the production rate on a cyclical basis to cyclically expand the reservoir and store energy in the form of elastic deformation while a production well produces continuously at a constant or fluctuating rate. Configurations of the present invention are still related to reservoirs that can be a) stacked vertically, but remain independent and isolated from adjacent reservoirs and b) arranged horizontally, but remain independent and isolated from adjacent reservoirs. The arrangement of the reservoirs will generally depend on the type and magnitude of the stress field associated with the local HDR formations. The synchronization of the loading and unloading of the systems can be synchronized to produce a sequence such that a cyclic state or a steady state or steady state with load following production cycles can be generated while still extracting coincident thermal and mechanical cycling that results in cracking or fracturing of the reservoir rock. Each of the production cycles will have specific production characteristics that can be matched with the final utilization of the heat energy. One method of heat production from this type of engineered reservoir is achieved through the development and production of one or more independently separate joint system groups via the coordinated cycling of a set of separate rock joint groups oriented vertically or horizontally to one another, such that there is a continuous production of thermal energy from the reservoir group for direct utilization applications as well as capacity following peak load for such end uses as generation. electricity. Another method of heat production from this type of engineered reservoir is carried out by developing and producing a single jointed reservoir with two or more wells in which the injection wells inject periodically or continuously at different injection rates, such that the rate is greater than the continuous production rate produced from the production wells, in such a way that the reservoir is alternately expanded and then allowed to contract to generate the combined thermal and mechanical stresses necessary to generate reservoir cracking 'in situ' while the reservoir is being produced at a continuous rate, either in steady state or head-following state, from the production well borehole.The principle in this case is the operation of the single reservoir in a manner that alternately charges the reservoir at a rate greater than the production rate to expand the reservoir and then reduces or terminates the injection cycle to allow the reservoir to contract in order to produce the reservoir from the stored energy of the reservoirs. This type of pressure recycling still provides the benefits of thermal and mechanical coincident cracking as described herein. BRIEF DESCRIPTION OF THE DRAWINGS A more complete understanding of the method and apparatus of the present invention can be obtained by reference to the following detailed description when taken together with the accompanying drawings, in which: Figure 1 outlines a simplified generic schematic view of a point-to-point directionally specific pressure source closed-loop circulation system designed to remove heat from rock formations; Figure 2 outlines an improved version of a system of Closed-loop circulation of fractured rock, a technique from the previous model, is being tested in modern developments such as the commercial dry hot rock experiment conducted by Geodynamics Limited of Australia; and Figure 3 outlines a generic schematic of a configuration of the HDR production system of this invention and its initial operating cycle. Figure 4 outlines a generic scheme of a second configuration of the HDR production system of this invention for generating geothermal heat energy. Figure 5 outlines a generic scheme of a third configuration of the HDR production system of this invention that uses geothermal heat energy to process organic carbon under supercritical conditions; Figure 6 is a diagrammatic illustration of the main components required to drill a geothermal well hole using the PJD methodology; Figure 7 is a schematic diagram of a wellhead and drilling system illustrating the use of various types of drilling methodologies in the exposure of hot dry rock to develop geothermal reservoirs; and Figure 8 is a flowchart illustrating a configuration of the principles of the present invention. DETAILED DESCRIPTION OF THE DRAWINGS The present invention will now be described more fully hereafter with reference to the accompanying drawings, in which preferred configurations of the invention are shown. This invention can, however, be configured in many different ways, and should not be construed as limited to the configurations described herein; rather, these Configurations are provided so that this disclosure may be complete and finished and may fully convey the scope of the invention to those skilled in the art. The present invention is based on the development of a discrete system of dilatable fractures in hot rock formations and the subsequent extraction of heat from the hot rock by elastically “inflating” and “deflating” the reservoir by injecting and recovering an injection fluid such as water. The joints in the rocks open when the reservoir pressure increases due to injecting water into the wellbore. The rock joints close when the reservoir pressure decreases due to the production of injection water that has been heated by the reservoir rock. This water can be pumped into the reservoir for storage, and can be withdrawn when water is needed, or its production can be synchronized to produce, in conjunction with other dilatable fracture systems, a continuous net flow of produced hot water. Figure 1 outlines an apparatus that was experimented with by Los Alamos National Laboratories to produce hot water from hot rock formations, in which the injection fluid, water in this case, was circulated in a continuous closed-loop manner. A wellbore 20 was drilled from the earth's surface 1 through underlying sedimentary-type formations 2 and Precambrian crystalline impermeable rock formation 10. Cold water 75 was pumped into the lined wellbore 20 to dilate the natural joints in the Precambrian formation to form a network of interconnected fracture mists or joints in the geothermal reservoir 15. Due to formation stresses of the Precambrian rock, the reservoir of interconnected fractures is typically elliptical or oblong in shape, and may be oriented horizontally, vertically, or any degree in between.A second wellbore 70 is drilled and cased in the geothermal reservoir 15 to create a subsurface system. A closed-loop circulation system of the specific pressure dissipator type, directionally point-to-point, could provide a path to the surface to produce heated geothermal fluid 80 from the reservoir. Once the reservoir has been generated and the wells drilled and cased, surface-based equipment is added to create a closed-loop circulation system. Wellheads 30 and 65 are installed over the wellbore casing, and a heat exchanger 45 is installed to capture the mined heat. Appropriate flow piping, control valves 60, and pumps 35 are installed. The well can then be circulated by injecting cooled water 75 via pump 35 through wellbore 20, exiting wellbore 20 into the geothermal reservoir 15 in the direction shown by arrow 25.Water flows through the reservoir in a specific, directionally point-to-point flow path created by the hydraulic pressure dissipator of production wellbore 70 and enters production wellbore 70 as shown by the arrow identifying heated geothermal fluid 85 and is thereby heated. The heated geothermal fluid 80 then returns to the surface through wellbore 70 and wellhead apparatus 65. The heated water flows through control valve 60, which is used to maintain adequate backpressure in the production wellbore to keep the dilated fracture joints open enough to minimize flow impedance between the wellbore sections. The heated water proceeds through heat exchanger 45 where the water is cooled by a heat exchange to a second fluid that is flowing through lines 40 to line 50. The cooled water is reinjected down into wellbore 20 by means of pump 35.This arrangement provides a device for draining water through the geothermal reservoir 15 from the injection wellbore 20 to the production wellbore 70 in what is generally considered a point-to-point circuit by means of a pressure differential between the wellbores. This type of arrangement does not allow... The use of the large quantity of heated water stored in the expansion joints that are not drained due to pressure isolation between the two wells. When the geothermal reservoir 15 reacts to long-term expansion pressure, the geothermal reservoir 15 tends to establish pressure equilibrium and therefore grows, increasing itself until pressure and thermal equilibrium are achieved. This process could require the continuous addition of large quantities of completion water that could be injected into the cooled water flowline at point 55, but normally isolated from the production cycle due to pressure isolation as described above. This type of water loss provides a significant disadvantage to the widely dispersed use of this form of HDR completion and production. The system described above suffers from high flow impedance during water circulation through geothermal reservoir 15. Attempts to increase production through increased injection pressure produce greater pressure stimulation of geothermal reservoir 15, causing additional reservoir equilibration related to expansion, with the resulting loss of additional water to the pressure isolation described above. Therefore, economical flow rates can only be achieved in this system by drilling multiple wells to provide additional flow at the ends of geothermal reservoir 15. The overall economics of the system are very sensitive to the total cost of the well holes. Therefore, in attempts to minimize drilling costs, the development of multiple wells and multiple fracture mist reservoirs is illustrated in Figure 2. Figure 2 illustrates injection well hole 70 and production wells 71 and 72 being drilled from the earth's surface through overlying sedimentary formations 2 and Precambrian rock formation 10. Well hole 10 is used as a development well to generate Hydraulically separate fracture mist lenses 16, 17, and 18. The method used to generate these wells is to run a casing string and cement above the bottom of the well. The uncased lower region of the well could be hydraulically pressurized to induce fracture / joint dilation. This lower section could then be hydraulically isolated by filling the lower section with sand to some predetermined height or a hole packing assembly below. The well could then be drilled above the height of the sand packing / hole packing isolation below and the well hydraulically pressurized to induce a second discrete fracture mist at some vertical distance above the lower fracture mist. Typically, these fracture mists should be oriented vertically to vertical heights above 3,000 feet (912 m).Due to the non-linear increase in drilling costs in Precambrian rock as a well is deepened, it is likely that only one or two lenses can be economically developed within the economic limits of the depth achievable with normal drilling processes. Once the repetitive cycle of developing the projected number of vertically spaced fracture mist systems has been completed, the sand packing designed to hydraulically isolate the lower wellbore sections can be removed via direct circulation to clear the sand plugs and expose the fracture mists below the injection wellbore to pressure and flow during production operations.In combination, injection well hole 70 and production well holes 71 and 72 develop a specific flow path directionally point-to-point through the production well hydraulic pressure sink in a closed-loop system that can generate a cumulative flow rate capable of producing commercial volumes of hot water or steam. A similar heat control and recovery system as that used in Figure 1 can be used in the system of... Figure 2. Figure 3 outlines a configuration of the completion scheme and production method of this invention, for producing heat energy for use in direct and indirect applications, such as producing bitumen and generating electricity. Wells 320, 325 and 330 are drilled from the earth's surface 1 through any sedimentary formations 2 overlying the Precambrian rock formation 10 into the interior of the Precambrian rock formation 10 to a sufficient temperature depth to allow the development of one or more discrete formation fracture joint mists, which are oriented vertically or horizontally as determined by the prevailing stress fields in the rock formation relative to each other. The deepest well 320 in the case of vertical orientation of the formation fracture mists may need to be drilled to a greater depth than 30.000 feet (9120 m) depending on the thermal gradient of the formation and the temperature required for the end user of geothermal heat, to achieve rock temperatures at the bottom of the borehole high enough to allow the development of one or more reservoirs above the bottom-hole reservoir. If fracture mist develops vertically due to the minimum principal stress being positioned vertically, then each fracture mist reservoir will need to be separated on the order of 5,000 feet (1520 m). The second deepest well, 325 in this case, might need to be drilled and cased to a depth of 25,000 feet (7600 m) and the third well, 320, might need to be drilled and cased to a depth of 20,000 feet (6000 m).The lowest portion of each well could be hydraulically fractured to produce a reservoir volume of expanded joints in the formation, pumping at pressures above the joint expansion pressure and toward the formation rupture pressure, which is estimated to be on the order of 1.0 psi / ft of depth (0.224 atm / m of depth). The wellbore should then be usable for the pressurization cycle to load the reservoir followed by depressurization of the reservoir to flush the heated water from the expansion joints and produce the heat absorbed by the water during the pressurization and depressurization cycle. The same wellbore completion process should be repeated in each of the other two shallower wells to develop an aggregate of the three discrete reservoirs, which could accept pressurized water to load the reservoir through the expansion joints, allowing the water to travel into the reservoir, be heated, and then expelled from the reservoir when the water pressure is lowered in the wellbore. Absorbed heat could be produced continuously by synchronizing the wellbore pressure cycling to provide a well that is injected at twice the rate at which the well is drained in reverse.By shifting the synchronization of the reverse flow cycle of these wells, it is possible to provide high continuous flow production from this reservoir arrangement. A similar process might be necessary to develop reservoirs that are horizontally spaced with the reservoirs in either vertical or horizontal orientation. Figure 3 shows the configuration required to produce continuous flow of high-flow heated water from three discrete reservoirs separated vertically from each other. Pre-loading pump 360 supplies cooled water from surface reservoir well 350 to injection pump 385. Injection pump 385 forces the cooled water under high pressure and volume into one of the three hot dry rock reservoirs (HDR). Injection pump 385 is sized to be able to fully load a single reservoir at a rate that is equal to the discharge rate of the heated water wash from the other two HDR reservoirs. In this way, a three-well production scheme could provide two wells producing at half the injection rate, thus providing continuous flow. This corresponds to the injection and production rate between the three wellbore holes. The wells are managed by alternately opening and closing the discharge control valves 410, 405, 400 and the injection control valves 390, 415, 420 to provide the proper sequence every 24 hours. High-volume heated water is brought to the surface by means of pressure energy stored in the rock during the loading cycle. The heated water is then conducted through a heat exchanger 45 where heat is transferred from the well discharge flow by flowing a second fluid through the heat exchanger lines 40 to 50. The cooled wellbore fluid is routed back down the wellbore through control valve 370 to injection pump 385.Alternatively, cooled wellbore fluid can be discharged from the heat exchanger to surface reservoir well 350 via line 380 and throttle valve 375 which controls system backpressure. Surface reservoir well 350 could be used to store any reserve water needed to supply supplemental water when reservoirs mature. Figure 4 outlines another configuration of the completion scheme and production method of this invention, for producing heat energy for use in direct and indirect applications such as producing bitumen and generating electricity. The well 40 should be drilled and lined from the earth's surface 1 through any sedimentary formations 2 that overlie the Precambrian rock formation 10 into the interior of the Precambrian rock formation 10 to a sufficient temperature depth to allow the development of discrete formation fracture joint mists, which are oriented vertically or horizontally as determined by the prevailing stress fields of the rock formation relative to each other. The geothermal reservoir 15 should be hydraulically fractured to produce a volume of The desired reservoir of expanded joints in the formation is designed by pumping a liquid at pressures above the expansion pressure of the joint and the rupture pressure of the formation, which is estimated to be on the order of 1.0 psig per foot of depth (0.224 atm / m depth). Additional wells 68, 69, and 20 should be drilled and cased into the geothermal reservoir 15 at a predetermined distance from the production well 70. The preferred configuration should utilize two wells 70 and 68. Figure 4 illustrates the use of an additional well 69 as an injection well, to illustrate the flexibility of the engineered nature of the present invention to resist parasitic pressure losses in the injection wells. Other additional production wells may be desirable to reduce parasitic pressure losses in the production wells. Wells 68, 69, and 20 should act as injection wells to pressurize the geothermal reservoir 15.Further fracturing of geothermal reservoir 15 may be desirable to increase the productive volume of geothermal reservoir 15, once injection wells 68, 69, and 20 have been drilled, cased, and hydraulic communication has been established with production well 70. Production well 70 should be used to produce injected fluids at a rate corresponding to the end-use. This production rate should be a) a constant production rate, b) a constant production rate with periodic increases and / or decreases to accommodate subsequent end-user load requirements, and / or c) a periodic start-up and stop-down rate tuned to the end-use requirements. Injection wells 68, 69, and 20 are designed to inject at a higher injection rate than is being produced in production well 70 until the maximum elastic energy of geothermal reservoir 15 is reached.The injection flow will then be cut off or terminated to allow the elastic deformation stored in the geothermal reservoir 15 to be relieved by emptying the reservoir and producing the heated water contained therein. Geothermal reservoir 15. The pressure level in geothermal reservoir 15 will be allowed to be reduced by relaxing the elastic deformation stored in geothermal reservoir 15 to a predetermined level, sufficient to maintain the expansion of the joints in geothermal reservoir 15. Once this predetermined level of relaxed elastic deformation has been relieved to the predetermined level, fluid injection will begin or increase as the case may be. This method of repeated expansion and deflation of geothermal reservoir 15 will produce a) omnidirectional flow of the injection fluid, establishing conditions that allow the production of injection fluid from omnidirectional flow paths towards the production well,b) simultaneous and / or periodic cycling alternating thermal and mechanical recycling to produce cracking or fracturing of the surface joint areas that produce surfaces with high thermal differentials recently exposed that can be swept of their heat, c) the arrangement of injection wells for production wells is designed to provide a secondary convection heat sweep when the fluid circulates through the geothermal reservoir 15, as well as the primary conduction heat sweep from the surface of the expanded joints d) the arrangement of injection wells for production wells is designed to minimize thermal depletion near the production well by remotely injecting the working fluid forcing it through both types,Conduction and convection flows. Geothermal reservoir 15 should be usable for the pressurization cycle to charge geothermal reservoir 15 followed by depressurization of geothermal reservoir 15 to wash the heated water from the expansion joints and produce the heat absorbed by the water during the pressurization and depressurization cycle. Figure 5 outlines another configuration of the completion scheme method and production method of this invention for producing and using geothermal heat energy for use in processing. Organic carbon under supercritical fluid conditions. The basic steps for processing organic carbon under supercritical conditions are well documented in the public domain. Examples include descriptions provided by Modell in Patent Number 4,113,446, issued on September 12, 1978, entitled “Gasification Process,” and further in Patent Number 4,338,199, issued on July 6, 1982, entitled “Processing Methods for the Oxidation of Organics in Supercritical Water.” Titmus et al. have described the use of deep-walled cased boreholes as pressure containment vessels in various configurations to continuously process chemical reactions using the various tubular configurations within the boreholes as pressure containment vessels and utilizing the natural hydrostatic head gradient within the borehole as a device to conveniently inject raw material and product recovery. Titmus describes this in Patent Number 3,853.Patent No. 759, issued on December 14, 1974, entitled “Dynamic Hydraulic Column Activation Method,” describes the method of using deep boreholes as reaction vessels to perform the continuous processing of various chemical reactions. Titmus further describes the use of deep boreholes for the purpose of reacting continuous chemical processes under supercritical water conditions in Patent No. 4,594,164, issued on June 10, 1986, and more in Patent No. 4,792,408, issued on December 20, 1988. The descriptions by Modell and Titmus require a chemical, electrical, or fuel-based process to initiate and then maintain the elevated internal temperatures within the reactor pressure vessel sections at temperatures necessary to promote supercritical water conditions.In Modell's description, the supercritical water condition pressure requirement is generated by a pumping device, and in Titmus's description, the supercritical water condition pressure requirement is achieved with the help of the natural hydrostatic head of the wellbore. The present invention combines certain understandings and aspects of... The teachings of Modell and Titmus are further enhanced by the aspect of providing an integrated geothermal heat production system to initiate and sustain chemical processes under supercritical fluid conditions through the use of a pressure vessel reactor system installed within the production well of a geothermal heat production system, as generically described in Figure 4. The configuration of Figure 5 builds upon the configuration of Figure 4 with the additional step of inserting a tubular reactor vessel 73 into the cased borehole 70 through the modified wellhead 64 to accept said tubular reactor vessel 73. In principle, the geothermal reservoir 15 is located in an HDR formation that provides the capacity to produce a supercritical fluid, preferably water. The geothermal production system is set up to circulate continuously as described in Figure 4 and will be exploited for its heat content to: a) heat the reactor vessel to promote a continuous chemical reaction within the reactor vessel; b) provide heat to generate useful work at the surface, such as generating electricity by circulating geothermal water produced from said geothermal reservoir 15 to the surface where it can be used; and c) preheat the organic feedstock as described herein. The configuration of the invention shown in Figure 4 is modified in the configuration of Figure 5 only in that the geothermal reservoir 15 is developed to such a depth as to produce geothermal fluid temperatures above 375°C and preferably above 450°C. The heated geothermal fluids 85 and 86 are flowed around a reactor vessel 73 placed concentrically within the cased borehole 70 to the surface. The produced heated geothermal fluids 85, 86, 80 and 81 conduct heat to the reactor vessel 73 to heat heterogeneous organic carbon suspension 761, 760, 770 and 771 to a temperature above 375°C. The produced heated geothermal fluids 80 and 81 are passed through wellhead 64, through control valve 750, through line 690 to heat exchanger 45, where the geothermal working fluid is expanded and then condensed to remove volume from its heat. The condensed geothermal fluid is then drained from heat exchanger 45 through line 590 where it is combined with effluent from the reactor vessel where the combined fluids are circulated through heat exchanger 605 to provide heat energy to preheat the heterogeneous organic carbon suspension as described herein below. A heterogeneous organic carbon suspension is formed within mixing processor 530 by combining water from water reservoir 200 pumped by pump 500 to mixing processor 530 via supply line 220 and 550 and organic carbon material and appropriate catalysts or retarders sourced from accumulation piles 570 via line 560. The heterogeneous organic carbon suspension is then pumped by pump 600 via line 580 and through heat exchanger 605 where the heterogeneous suspension is preheated by means of final entropy transfer from the produced geothermal heated fluid 80. The heterogeneous organic carbon suspension flows via line 610 from heat exchanger 650 to the annular space of the reactor vessel via wellhead 730.The heterogeneous organic carbon suspension is thus pumped down into the annular space between the concentric walls of reactor vessels 73 where it is heated above the supercritical water temperature by the action of heated geothermal fluids 808, 185 and 86 produced from the geothermal reservoir 15. When the heterogeneous organic carbon suspension is pumped down the reactor vessel ring it is subjected to pressures greater than supercritical water pressures, at which point the heterogeneous organic carbon suspension reacts and forms a single-phase fluid with some non-organic precipitates. The length of the reactor vessel flow path is such that the time of . The residence of organic material under supercritical water conditions provides sufficient circulation time to accommodate the reaction time required for the dissociation of the organic material into its elemental constituents. The fluid is drained or pumped around the end of the reactor vessel 800 into the interior of the reactor vessel 800 through chamber 773 where the produced fluid 741, 740 is returned to the surface through wellhead 720. The produced fluid 741, 740 heats the descending heterogeneous organic carbon suspension as it passes through the common tubular wall of the reactor vessel 800. The produced fluid 740 passes through wellhead 720 to particulate separator 620, where the inorganic particulate product of the process is separated from the liquid stream and where the solid particulate is passed through line 710 to the solid particulate storage vessel 700.The clarified produced fluid then passes through flow line 660 via control valve 650 to gas separator 641, and the clarified produced fluid is processed to allow the gases to be separated from the liquid component of the clarified produced fluid. The gases are removed through line 670 and further separated into their various species in gas classifier 680 and are then removed for further processing. The available heat energy from the clarified produced fluid is recovered in heat exchanger 45 to produce useful heat energy. The fluid then flows from heat exchanger 45 to line 591 where it is mixed with the fluid resulting from the heat exchange process of the heated produced geothermal fluids 80 and 81.The mixed effluents from heat exchanger 45 are conveyed to heat exchanger 605, and any residual heat is further exchanged as a preheating process for the heterogeneous organic carbon suspension being drained through heat exchanger 605. From heat exchanger 605, the fluid effluent is drained through line 540, through control valve 520, and through line 510 to be... discharged into water reservoir 200. The configuration in Figure 5 provides a method of utilizing geothermal heat energy contained in produced geothermal fluids that are above 375°C to initiate and / or maintain a continuous or periodic supercritical reaction in a reactor vessel immersed within said geothermal production well. Figure 6 illustrates the main components required to drill a geothermal well using PJD methods. It is common knowledge that drilling large-diameter deep wells in Precambrian rock is prohibitively expensive with commonly practiced mechanical rotary earth formation drilling practices. The slow penetration speed associated with mechanical rotary drilling systems has been the main cause of the enormous potential for extending HDR geothermal energy resources being weakened. The use of PJD techniques and methods provides a means to increase the penetration speed in all formations, and particularly crystalline rocks, sufficiently to reduce time and cost to a level that will provide the potential for widespread use of geothermal energy. The experimental use of PJARMD designed for drilling oil and gas wells has been well documented by the oil and gas industry. The experimental use of high-mass particles entrained in boreholes by drilling fluids was demonstrated by Gulf Oil Company in early 1969 based on US Patent 3,348,189 issued on May 21, 1968, and the more recent use of larger-diameter high-mass particles entrained in drilling fluid was patented by the inventor as US Patent 6,386,300 issued on May 14, 2002. The referenced methods of drilling with jetted particles constitute the process of dragging discrete high-density solid particles into the circulated drilling fluid during the drilling operation to jet the particle out of suspension. The process is driven against the formation, thereby cutting the formation through the momentum energy imparted to the rock by the quantity of motion transmitted from the action of the high-mass particles. Both PJARMD and HPJD processes have been successfully demonstrated in laboratory tests to increase the penetration speed of drilling in various earth formations. Certain experimental field tests were conducted in sedimentary formations. From then until now, PJARMD has been developed and tested for the commercial purpose of drilling sedimentary formations that hold oil and gas reserves. These sedimentary formations are generally found above Precambrian rock formations. Sedimentary formations consist of stratified shale, sandstone or limestone and / or their metamorphosed material.Drilling in sedimentary formations using PJARMD techniques involves the use of a rotary mechanical drill bit that is assisted by the use of jetted particles. PJARMD requires careful balancing of the properties of the suspension fluid and operating parameters. The effective circulation density (ECD) of the drilling suspension fluid containing high-mass particles must be carefully maintained so as not to disrupt any sedimentary formations such as shale, sandstone, or limestone. The need to carefully control ECD in sedimentary formations is expected to be a significant limiting factor in the widespread use of PJD as a device for drilling oil and gas wells in sedimentary formations due to the potential for chronic and problematic formation disruption known as loss-of-circulation conditions.Secondly, the use of PJARMD methods is better suited for relatively smaller wellbore diameters used in oil and gas production. The use of HPJD techniques to drill Precambrian rocks at great depth is essential for development. Deep HDR geothermal resource economics. HPJD can be used in competent borehole formations where ECD is not a controlling factor. In formations such as the Precambrian and Hadean crystalline formations, they themselves lead well to minimized ECD effects, thus allowing full utilization of HPJD without the need for rotary mechanical drilling assistance. Figure 6 illustrates a method of drilling a deep borehole terminating in crystalline rock for the purpose of generating an HDR geothermal reservoir. The generic geometry illustrates the sedimentary rock formations 870, 860, and 850 which typically overlie Precambrian rock formation 840. The sedimentary formations 870, 860, and 850 are generically stratified formations of different sedimentary rock materials such as shale, sandstone, and limestone.These formations can be drilled by any standard rotary mechanical device or PJARMD as is appropriate for the composition and thickness of the sedimentary section. The sedimentary section of the wellbore 880 will be isolated from the deeper wellbore 920 by means of a tubular casing 890 which is typically cemented in place by a cement sheath 900. The drill pipe 910 which is manipulated by a drilling rig (not shown) provides the connection of the tubular conduit to the HPJD drill bit 810. The HPJD drill bit 810 provides the device for jetting the accelerated high-mass particles 830 within the jet flow of a typical PJD drill bit 820 onto the Precambrian rock formations to rapidly drill said formations.The innovation of drilling through and isolating the sedimentary formation to expose only the crystalline Precambrian formation for drilling using HPJD methods provides the ability to utilize optimal HPJD operating conditions to maximize penetration speed when drilling said Precambrian formations, which are not available when drilling sedimentary formations. The use of low viscosity fluids for... HPJD particle drag, transport, shock, and return circulation operations are thus available for drilling in Precambrian formations since there is no need to significantly consider ECD properties due to the integrity of the Precambrian formation, as opposed to the lack of integrity of wellbore exposed to sedimentary formations. The use of very high PJD fluid flow rates can also be employed when drilling Precambrian formations since there is no need to significantly consider drilling formation erosion by the drilling fluid again due to the integrity of the Precambrian formations. The use of PJD methods to reduce the cost of drilling well holes that terminate in Precambrian or Hadean formations is fundamental to the broad development of HDR potential. Specifically, PJD provides a means to economically drill very deep, large-diameter injection and production well holes for HDR production purposes. The specific well hole geometry used in conjunction with PJD techniques is unique in producing the environment to operate PJD techniques at optimal levels for penetration rate performance purposes. Referring now to Figure 7, it shows a schematic diagram of well drilling within a plurality of earth formations. At wellhead 400, represented by the diagrammatic illustration of a crane, a first earth formation 404 is penetrated by wellbore 402. The type of drill bit used in this particular formation may be a conventional mechanical drill bit for shallow wells and / or the PJARMD referenced here. Diagrammatically represented in the lower earth formation 406 is a drill bit 414 which may be the same and / or similar to drill bit 412, but may vary according to the The principles of the present invention depend on the type of earth structure found in earth section 406. Similarly, earth section 408 is a continuation of wellbore 402 and illustrates, diagrammatically, a drilling bit that may be of a different methodology according to the principles of the present invention, depending on the type of structure engaged in the earth formation 408.Finally, the earth formation 410 is diagrammatically represented as a Precambrian and / or Hadean crystalline rock in which its cross-sectional profile is varied, and the wellbore section 430 is shown penetrated by a hydraulic drilling methodology found in the drilling tool 418 which may incorporate particle jet drilling, according to the principles of the present invention, to penetrate the Precambrian or Hadean crystalline rock formation to access the thermal source therein and establish a location within the wellbore for subsequent hydraulic fracturing and the loading and unloading described above, according to the principles of the present invention. Referring now to Figure 8, it shows a flowchart of a configuration of the principles of the present invention. In this particular flowchart, the methodology described above is clearly established and shown, in which step 501 includes the establishment of a wellbore drilling system according to the principles of the present invention. Step 503 illustrates the drilling of a first borehole section using a PJARMD methodology. This methodology may change depending on the particular type of earth formation as illustrated in Figure 7. Still referring to Figure 8, step 505 represents the borehole that reaches the Precambrian or Hadean crystalline rock formation where the type of drill bit being used may vary according to the principles of the present invention. Step 507 illustrates Drilling the second lower borehole section through the Precambrian or Hadean crystalline rock formation using hydraulic drilling methodology. One form of the HPJD methodology established and described in the present invention is particle jet drilling. Step 509 illustrates the hydraulic fracturing of the hard dry rock HDR to produce a dilated joint fracture mist. Step 511 illustrates the loading and unloading of the fracture mist according to a configuration of the principles of the present invention. Step 513 illustrates producing thermal energy from the fracture mist according to the principles of the present invention, as described above. In summary, the above-referenced description has outlined and demonstrated the following innovative aspects of the present invention: 1. The use of HPJD for drilling well holes that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 2. Method of drilling and isolating sedimentary formations with or without PJD methods for the purpose of drilling underlying non-sedimentary crystalline Precambrian or Hadean formations using PJD techniques. 3. The use of a non-rotating mechanical device to drill wells that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 4. The use of a non-mechanical drilling device to drill well holes that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 5. The use of low viscosity or Newtonian drilling fluid in conjunction with PJD to drill wellbores that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 6. The use of PJD fluid flow rates equal to or greater than 500 gallons per minute (31.5 liters / second) to drill well holes that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 7. The use of non-standard drill pipe to drill well holes that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. 8. Use PJD methods to drill well holes that are 9 inches (23 cm) or larger in diameter that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. Utilize PJD methods to drill well holes that are 5,000 feet (1520 m) deep or greater that terminate in a) non-sedimentary formations or b) Precambrian or Hadean formations for the purpose of developing hot dry rock geothermal resources. The following concepts are thus considered within the spirit and scope of the present invention: 1) In HDR reservoir generation, the conventional thinking is to continuously circulate between two or more wells through flow paths in induced rock fractures or to dilate the natural rock joints that occur in the HDR reservoir. This short-circuiting Hydraulic or point-to-point flow is simultaneously limiting in its capacity to 1) absorb heat, 2) withstand high flow impedance, and 3) hydraulically isolate the fluid volume contained in the fracture mist reservoir. The method of this invention provides elastic cycling of the loading and unloading of a reservoir that provides full utilization of the reservoir fracture system through omnidirectional flow during the loading process, and reverse omnidirectional flow during the reservoir relaxation process. Furthermore, the ability of water to absorb heat is a function of its residence time when in contact with the surface area of ​​the reservoir.This method provides relatively longer water residence times, as the water must first be washed into the rock joints and then washed out of the rock joint sequentially during the formation loading and relaxation cycle. Furthermore, the omnidirectional flow provides a vastly increased surface area for the water to be heated during each cycle, compared to conventional HDR completion systems. This double-pass flow regime will provide significantly improved heat transfer to the produced water. 2) The use of cyclic reversals of both mechanical and thermal stress will provide significant surface rock breakage over time due to these combined cyclic stress reversals. By breaking the reservoir rock into relatively small blocks or into tubes or chunks of rock through shearing or fracturing, the reservoir surface area and reservoir volume are increased, providing an increasing area from which to draw heat when omnidirectional fluid paths sweep across the surface area of ​​the “hydraulic vessel”. The stacked rock is hydraulically isolated once it has broken free from the fracture surface. Gravity will pull the separated rock into the regions The lowest points of the reservoir, where it will be pulverized over time through the action of mechanical drying of the reservoir rock. There are two thermal mechanisms for bringing heat during conduction in this scenario: near-field and far-field heat conduction. Near-field heat is transferred by conduction very rapidly due to the high temperature differentials between the rock and the sweep fluid. Once this near-field heat is removed to a lower threshold, further heat transfer is governed by the average diffusivity values ​​of the rock. By far the greatest heat sweep effects are gained by the continuous exposure of the injection fluid to the near surface of the hydraulic vessel due to the related cyclic shear cracking.It is expected that shear cracking will continuously occur on a new contact surface to interact with the injection fluid before the elevated heat levels of the near-field region have been reduced to a level that triggers far-field heat diffusivity to act on the reservoir wall, thus reducing the heat transfer rate. The described action provides a near-continuous cooling of the elevated temperature differentials available for conductive near-field heat sweeping over time. This is the opposite of conventional HDR systems that must rely on far-field heat diffusivity from the far-field rock mass once the near-field heat has been conductively swept away, which has the effect of significantly lowering the total heat output and production temperature over time.Therefore, the ability to generate new surface area in an expanding reservoir is key to sustaining the type of near-field driving values. When the rock reacts to the thermal and mechanical stresses of repeated cycling during production, new surface area is generated as the rock contracts with the effects of thermal change as well as coincident mechanical displacement acting on the surface. from the inner rock of the reservoirs, a "hydraulic vessel". 3) The reservoir can be enlarged through additional fractionation above the fracture expansion pressures to extend or generate a larger base reservoir. This could serve the purpose of increasing the size of the base reservoir, developing the base reservoir more rapidly than would be possible with just the cyclic action of loading and unloading cycles, and compensating for maintaining temperature in the reservoir if necessary. 4) This geothermal production method produces a significantly higher production rate and, ultimately, greater potential for recovery than any other method currently being used, due to increased surface area sweep and new surface exposures over time. 5) The use of geothermal temperatures produced above 375°C to provide heat energy to support chemical reactions in a reactor vessel immersed in the geothermal production well provides the basis for converting large volumes of organic carbon such as coal, oil shale, biomass and tailings into usable and marketable products. The geothermal heat energy produced provides a) the heat energy to initiate or sustain the supercritical water chemical process within the reactor vessel, b) provides residual heat energy to drive direct and indirect use of the produced geothermal fluid for such end uses as generating electricity through binary-type power generation plants, and c) provides additional heat production to preheat the organic carbon feedstock.The system derives its economic value from generating clean electricity and producing clean-burning hydrogen while separating and capturing any harmful byproducts in forms that can be further processed, disposed of, or effectively marketed. The use of the cyclic geothermal reservoir flexibility production method for... Providing steady-state production from a single reservoir and offering the benefits of cyclic injection to maintain high thermal production temperatures, flow rates, and reservoir growth supports the capability to utilize continuous large-scale geothermal production, as opposed to batch processing of organic carbon such as coal, oil shale, biomass, and tailings to produce clean water and marketable products such as H2, methane, or Fischer-Tropsch liquids. This system could be useful in processing coal in existing power plants and supplying them with clean-burning fuel gases to enhance economics and reduce industrial greenhouse gas emissions. There are currently approximately 700 coal-fired power plants in the United States alone that could significantly benefit from this invention.Furthermore, this invention provides an enabling technology for the large-scale processing of mineable shale oil. It is believed that the operation and construction of the present invention will be evident from the preceding description of the preferred embodiments. Although the configurations and designs as shown are described as being preferred, it will be obvious to a person of ordinary skill in the art that various modifications and changes can be made to them without departing from the spirit and scope of the invention as defined in the following claims. Therefore, the spirit and scope of the claims should not be limited to the description of the preferred embodiments contained herein.

Claims

CLAIMS 1. A method of extracting thermal energy from a rock formation, characterized by comprising the following steps: Drill a plurality of wells to a sufficient depth to allow the development of at least one fracture joint mist reservoir; to hydraulically fracture at least one of the plurality of wells; to expand at least one reservoir of fracture joint mist; to force cooled water under high pressure and volume into at least one of the plurality of wells to fill the reservoir; to alternately open and close a plurality of discharge control valves and a plurality of injection control valves to provide continuous flow from the plurality of wells and allow discharge from the reservoir; to remove heated water from wells; and Pass the heated water to a heat exchanger.

2. Method according to claim 1, characterized in that the drilling step includes the hydraulic drilling step.

3. Method according to claim 2, characterized in that the hydraulic drilling step includes particle jet drilling.

4. Method according to claim 1, characterized in that the volume of at least one fracture joint mist reservoir is increased through simultaneous mechanical and thermal cycling.

5. Method according to claim 1, characterized in that heat values ​​in at least one fracture joint mist reservoir are maintained through mechanical and thermal cycling of the reservoir rock.

6. Method according to claim 5, characterized in that the volume of heat that can be swept in at least one fracture joint mist reservoir is increased through thermal and mechanical cycling of the reservoir rock.

7. Method according to claim 1, characterized in that the loading and unloading step of the system also includes the step of synchronizing the loading and unloading to produce a sequence of cycles with steady-state loading followed by production cycles generated simultaneously, which also induces coincident thermal and mechanical cycling that results in cracking and fragmentation of the reservoir rock.

8. Method according to claim 7, characterized in that the heat production method is further facilitated by the use of at least two wells, wherein an injection well injects periodically at different injection rates, such that the rate is greater than the continuous production rate produced from the production well, such that the reservoirs alternately expand and then are allowed to contract to generate the combined thermal and mechanical stresses necessary to generate “in situ” reservoir cracking while the reservoir is producing at a continuous rate.

9. Method according to claim 7, characterized in that the method is further facilitated by using at least three wells.

10. Method of completing geothermal production wells, characterized by including the steps of to drill a plurality of wells from at least one wellhead through a plurality of land formations; Use a first type of drilling bit to penetrate the uppermost ground formations to create a well hole; use a particle jet drilling bit to drilling a borehole within a region of hot, dry rock located beneath the first region of soil; to complete a first plurality of boreholes in a first Precambrian formation to a sufficient temperature depth to allow the development of one or more discrete formation fracture joint mists that are oriented vertically or horizontally as determined by the rock formation; to complete a second series of boreholes into the interior of a lower region to create a lower fracture joint mist generally positioned horizontally below the first mist; and Hydraulically fracture each mist to produce a reservoir volume of expanded joints in the formation by pumping at pressures above the joint expansion pressure and the formation rupture pressure.

11. Method according to claim 10, characterized because it also includes finishing a third borehole located below the termination areas of the first and second boreholes.

12. Method according to claim 10, characterized in that the fracturing step includes providing a pressurization cycle to charge the reservoirs followed by depressurization of the reservoir to wash the heated water from the expansion joints that produce the heat absorbed by the water during the pressurization and depressurization cycle.

13. Method according to claim 12, characterized in that it further includes repeating the process of charging and depressurizing each mist to develop an aggregate of a plurality of discrete reservoirs that will accept pressurized water to charge the reservoir during expansion of the joints allowing the water to move into the reservoir to be heated and then expelled from the reservoir when the pressure of heated water is reduced in the wellbore of a wellhead.

14. Method according to claim 13, characterized because it includes the step of continuously producing heated water by synchronizing the pressure cycling of the wellbore to supply a well that is being injected at twice the rate at which the well is drained in reverse.

15. Method according to claim 14, characterized in that it further includes routing cooled fluid from the wellbore, back down the wellbore through a control valve to an injection pump.

16. Method according to claim 14, characterized in that it further includes discharging cooled wellbore fluid from the heat exchanger to a surface reservoir orifice.

17. Method according to claim 1, characterized in that the fracturing step comprises the step of dilating a plurality of material joints in the formation.

18. Method according to claim 1, characterized in that the drilling step includes drilling a portion of the upper wellbore with a rotary mechanical drilling bit.

19. Method according to claim 18, characterized in that the rotary mechanical drilling bit comprises PJARMD methodology.

20. A method of drilling deep well holes from a wellhead into Precambrian and Hadean eon crystalline rock formations to access thermal energy within them, characterized by comprising the following steps: Establish a borehole drilling system from the wellhead with at least one first and one second type of drilling methodology, the first methodology including rotary mechanical drilling and a second methodology including hydraulic drilling; Drill a first section of borehole from the wellhead into the interior of a first formation using the first rotary mechanical drilling methodology; Drill a second borehole section below the first borehole section into the interior of the crystalline rock formation using the second hydraulic drilling methodology; and to expose the thermal energy within the crystalline rock in order to access it.

21. Method according to claim 20, characterized in that the hydraulic drilling includes particle jet drilling.

22. Method according to claim 21, characterized in that the particle jet drilling methodology includes the process of dragging discrete solid particles of high density in a drilling fluid to cut the formation.

23. Method according to claim 22, characterized in that the formation cutting utilizes impulse energy imparted to the formation by momentum transmitted to the particles carried by the blasting fluid to wear down and crack the formation.

24. Method according to claim 23, characterized in that it further includes removing the worn formation at a rapid rate by means of fluid flow around it.

25. Method according to claim 21, characterized in that it further includes completing the wellbore to access a thermal energy reservoir in the formation by means of the steps of dilating a group of joints to form the reservoir, alternately loading and unloading the group of joints with a fluid to dilate the reservoir and causing the fluid to pass into the interior and then subsequently flow out of the reservoir.

26. Method according to claim 25, characterized in that it further includes the cyclic induction of simultaneous mechanical and thermal stress reversals in the reservoir rock, causing the rock to continuously form cracks and then expose new reservoir rock surface (shear bond).

27. Method according to claim 26, characterized in that it further includes the step of imparting several voltage reversals to create a continuous and incremental increase in high differential thermal surface area and reservoir volume, whereby the ability to continuously sweep heat from the rock formation in a manner that allows very high efficiency in removing a greater amount of available heat density per unit volume is provided.

28. Method according to claim 27, characterized in that the reservoir system comprises a single discrete reservoir that is independently cycled to produce a cyclic or periodic output.

29. Method according to claim 28, characterized in that the reservoir system includes a set of several independent reservoirs that can be situated in sequence so as to produce a continuous production flow that can be steady-state or floating.

30. A method for developing a high-temperature hot dry rock geothermal reservoir to access geothermal heat energy therein and produce it from the reservoir, characterized by comprising the following steps: Establish a borehole drilling system with at least one first and one second type of drilling methodology, the first methodology including rotary mechanical drilling and the second methodology including hydraulic drilling; drill a first section of borehole using the rotary mechanical drilling; Drill a second borehole section below the first borehole section into the interior of crystalline rock using hydraulic drilling methodology; to expose the thermal energy within the crystalline rock in order to access it; to fracture the crystalline rock into a fracture mist with at least some of the fractures in direct communication with the second borehole section; Pump fluid from the borehole down the first and second boreholes to hydraulically expand the fractures; and Alternating the hydraulic expansion and contraction of the fracture mist generates coincident thermal and mechanical cycling of the hot dry rock formations and periodic fracturing within the hot dry rock formation, whereby fracturing serves the purpose of incrementally exposing new high differential thermal services on an incremental basis that will serve the purpose of maintaining high temperature output in the hot dry rock formation.

31. Method according to claim 30, characterized in that the hydraulic expansion is effected in an omnidirectional manner simultaneously during the injection cycle and the production cycle to substantially increase the surface area swept by the working fluid.

32. Method according to claim 30, characterized in that the hydraulic drilling includes particle jet drilling.

33. Method according to claim 32, characterized in that the particle jet drilling methodology includes the process of dragging discrete solid particles of high density in a drilling fluid to cut the formation.

34. Method according to claim 33, characterized in that the formation cutting utilizes momentum energy imparted to the formation by momentum transmitted to the particles carried by the blasting fluid to wear down and crack the formation.

35. Method according to claim 34, characterized in that it further includes removing the worn formation at a rapid rate by means of fluid flow around it.

36. Method according to claim 30, characterized in that the reservoir system comprises a single discrete reservoir that is independently situated to produce a cyclical or periodic output.

37. Method according to claim 30, characterized in that the reservoir system includes a set of several independent reservoirs that can be situated in sequence, so as to produce a continuous production flow that can be either steady-state or floating.

38. A method according to claim 30, characterized in that it further includes a single reservoir having several wells that serve the purpose of simultaneous injection and production, in such a way that the injection wells periodically inject at a rate that exceeds the production rate on a cycle basis to cyclically expand the reservoir and store energy in the form of an elastic column, while a production well produces continuously at a constant or fluctuating rate.

39. Method according to claim 38, characterized in that the tanks are stacked vertically while remaining independent of each other.

40. Method according to claim 38, characterized in that the reservoir is generally arranged horizontally while remaining independently isolated from one another.

41. A method for developing geothermal reservoirs in hot dry rock formations, characterized by including the following steps: Establish a borehole drilling system with at least one first and one second type of drilling methodology, the first methodology including rotary mechanical drilling and the second methodology including hydraulic drilling; Drill an initial section of borehole using rotary mechanical drilling; Drill a second borehole section below the first borehole section into the interior of the crystalline rock using hydraulic drilling methodology; to expose the thermal energy within the crystalline rock for access to joints within it; to expand a group of joints to form a reservoir; and Alternately load and unload the joint assembly with a fluid to expand the reservoir, causing the fluid to enter and then drain out of the reservoir.

42. Method according to claim 41, characterized in that it further includes the cyclic induction of simultaneous reversals of mechanical and thermal stress in the reservoir rock, causing the rock to continuously exhibit cracks and thereby expose new reservoir rock surface.

43. Method according to claim 41, characterized by including the step of applying several voltage reversals to create a continuous and incremental increase in surface area at the high thermal differential of the surface area and volume of the reservoir, whereby the ability to continuously sweep heat from the rock formation in a manner that allows for very high yield by removing a quantity The highest density of available heat per unit volume is provided.

44. Method according to claim 41, characterized in that the reservoir system comprises a single discrete reservoir that is independently cycled to produce a cyclic or periodic output.

45. Method according to claim 41, characterized in that the reservoir system includes a set of several independent reservoirs that could be situated in sequence so as to produce a continuous production flow that can be steady-state and / or floating.

46. ​​A method according to claim 41, characterized in that it further includes a single reservoir having several wells that serve the purpose of simultaneous injection and production in such a way that the injection wells periodically inject at a rate that exceeds the production rate on a cycle basis to cyclically expand the reservoir and store energy in the form of an elastic column, while a production well produces continuously at a constant or fluctuating rate.

47. Method according to claim 46, characterized in that the tanks are stacked vertically while remaining independent of each other.

48. Method according to claim 46, characterized in that the reservoirs are generally arranged horizontally while remaining independently isolated from each other.

49. Method according to claim 41, characterized in that the loading and unloading step of the system also includes the step of synchronizing the loading and unloading to produce a sequence of steady-state load cycles following production cycles generated simultaneously that also induce coincident thermal cycling and mechanical factors that result in the cracking and fragmentation of the reservoir rock.

50. Method according to claim 41, characterized in that it further includes drilling at least two wells in which an injection well periodically injects at different injection rates, such that the rate is greater than a continuous production rate produced from a production well, such that the reservoirs alternately expand and are then allowed to contract to generate the combined thermal and mechanical stresses necessary to generate “in situ” reservoir cracking while the reservoir is producing at a continuous rate.

51. Method of completing geothermal production wells, characterized by including the following steps: Drilling multiple wells using multiple sources of land information; Use a first type of drilling bit to penetrate the uppermost ground formations to create a well hole; Use a particle jet drilling rig to create a borehole within a region of hot, dry rock located below the first region of soil; to complete a first borehole in a first Precambrian formation to a sufficient temperature depth to allow the development of one or more discrete formation fracture joint mists that are oriented vertically or horizontally as determined by the rock formation; to complete a second series of boreholes into the interior of a lower region to create a lower fracture joint mist generally positioned horizontally below the first mist; and hydraulically fracture each mist to produce a volume from reservoir of expansion joints in the formation pumping at pressures above the expansion pressure of the joint and the rupture pressure of the formation.

52. A method of extracting thermal energy from a rock formation, characterized by comprising the following steps: to drill one or more wells to a sufficient depth to allow the development of at least one reservoir consisting of fractures or joints within the rock formation; to hydraulically fracture or dilate the natural joints in the formation through at least one of the wells; to widen at least one fracture or joint within the rock formation, thereby forming a reservoir; to force cooled water under high pressure and volume into at least one of the plurality of wells, to charge the reservoir and create elastic stress within the surrounding rock; alternately open and close at least one set of discharge control valves and at least one set of injection control valves, to provide flow to and from at least one of the wells and allow alternating loading and unloading to and from the reservoir; remove heated water from wells; to remove at least a portion of the heat from the produced water and to use the heat produced from the heated water for thermal purposes.

53. Method of generating geothermal production wells, characterized by including the steps of to drill a plurality of wells from the surface through a plurality of land formations; Use a first type of drilling system and method to drill through the first sedimentary earth formation. superior for wellbore generation; to use a second type of drilling system and method for creating the borehole within a non-sedimentary region located below the first sedimentary region of land; To complete a first plurality of well holes in a first Precambrian formation at a sufficient temperature depth to allow the development of one or more discrete formation fracture joint mists, which are oriented as determined by the “in situ” stress fields of the rock formation; to complete a second series of boreholes into the interior of a lower region to create a lower fracture joint mist generally positioned horizontally below the first mist; and Hydraulically fracture each mist to produce a reservoir volume of expanded joints in the formation by pumping at pressures above the joint expansion pressure and the formation rupture pressure.

54. A method of drilling deep well holes from a wellhead into Precambrian crystalline rock formations to access thermal energy within them, characterized by comprising the following steps: Establish a borehole drilling system for drilling from the surface with at least one first and one second type of drilling methodology, the first methodology including rotary mechanical drilling or PJARMD, and a second methodology including hydraulic drilling or HPJD; Drill a first borehole section from the surface into the interior of a first formation using the first PJARMD methodology; Drill a second borehole section below the first borehole section in the crystalline rock formation with the second hydraulic drilling methodology; and to expose the thermal energy within the crystalline rock in order to access it.

55. Method according to claim 54, characterized in that the formation cutting utilizes momentum energy imparted to the formation by means of momentum transmitted to the particles carried by the blasting fluid to wear down or crack, or generally cut the formation.

56. A method for developing a high-temperature hot dry rock geothermal reservoir to access and produce geothermal heat energy therefrom, characterized by comprising the following steps: Establish a borehole drilling system with at least one first and one second type of drilling methodology, the first methodology including rotary mechanical drilling or PJARMD and a second methodology including hydraulic drilling; Drill an initial borehole section using rotary mechanical drilling or PJARMD; Drill a second borehole section below the first borehole section into the interior of crystalline rock using hydraulic drilling methodology; to expose the thermal energy within the crystalline rock in order to access it; to fracture the crystalline rock to form a fracture mist with at least some of the fractures in direct communication with the second borehole section; Pumping borehole fluid down the first and second borehole sections to hydraulically expand the fractures; and Alternating the hydraulic expansion and contraction of the fracture mist generates coincident thermal and mechanical cycling of hot dry rock formations and periodic fracturing within the hot dry rock formation, whereby the fracturing serves the purpose of incrementally exposing new high differential thermal surfaces on an incremental basis that will serve the purpose of maintaining high temperature production in the hot dry rock formation.

57. Method according to claim 56, characterized in that the hydraulic expansion is effected in an omnidirectional manner simultaneously during the injection cycle and the production cycle, to substantially increase the surface area swept by the working fluid.

58. A method of processing chemical reactions, characterized by the use of a reactor vessel immersed in a geothermal production well to allow geothermal heat energy to initiate, sustain, and / or support the conditions and / or reactions within the reactor vessel to drive chemical reactions.