WO1994021889A2 - Ameliorations concernant les forages et l'extraction de fluides - Google Patents

Ameliorations concernant les forages et l'extraction de fluides Download PDF

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Publication number
WO1994021889A2
WO1994021889A2 PCT/GB1994/000515 GB9400515W WO9421889A2 WO 1994021889 A2 WO1994021889 A2 WO 1994021889A2 GB 9400515 W GB9400515 W GB 9400515W WO 9421889 A2 WO9421889 A2 WO 9421889A2
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WO
WIPO (PCT)
Prior art keywords
shows
drilling
well
bore
reservoir
Prior art date
Application number
PCT/GB1994/000515
Other languages
English (en)
Other versions
WO1994021889A3 (fr
Inventor
John North
Original Assignee
John North
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Priority claimed from GB939305532A external-priority patent/GB9305532D0/en
Priority claimed from GB939317690A external-priority patent/GB9317690D0/en
Priority claimed from GB939319994A external-priority patent/GB9319994D0/en
Priority claimed from GB939321003A external-priority patent/GB9321003D0/en
Application filed by John North filed Critical John North
Priority to AU62147/94A priority Critical patent/AU6214794A/en
Publication of WO1994021889A2 publication Critical patent/WO1994021889A2/fr
Publication of WO1994021889A3 publication Critical patent/WO1994021889A3/fr

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Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F04—POSITIVE - DISPLACEMENT MACHINES FOR LIQUIDS; PUMPS FOR LIQUIDS OR ELASTIC FLUIDS
    • F04C—ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT MACHINES FOR LIQUIDS; ROTARY-PISTON, OR OSCILLATING-PISTON, POSITIVE-DISPLACEMENT PUMPS
    • F04C13/00—Adaptations of machines or pumps for special use, e.g. for extremely high pressures
    • F04C13/008—Pumps for submersible use, i.e. down-hole pumping
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
    • E21B10/32—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
    • E21B10/322—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools cutter shifted by fluid pressure
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B10/00—Drill bits
    • E21B10/62—Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B4/00—Drives for drilling, used in the borehole
    • E21B4/18—Anchoring or feeding in the borehole
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/25—Methods for stimulating production
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/30—Specific pattern of wells, e.g. optimizing the spacing of wells
    • E21B43/305—Specific pattern of wells, e.g. optimizing the spacing of wells comprising at least one inclined or horizontal well
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH DRILLING; MINING
    • E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B7/00—Special methods or apparatus for drilling
    • E21B7/04—Directional drilling
    • E21B7/06—Deflecting the direction of boreholes
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F24—HEATING; RANGES; VENTILATING
    • F24T—GEOTHERMAL COLLECTORS; GEOTHERMAL SYSTEMS
    • F24T10/00—Geothermal collectors
    • F24T10/20—Geothermal collectors using underground water as working fluid; using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/10—Geothermal energy

Definitions

  • a tool for use in the drilling of wells comprising a main body, a calliper body, a plurality of segments movable with respect to the calliper body in a radial direction with respect to the well bore, and a mechanism for moving the main body with respect to the calliper body.
  • a drilling motor for use in the drilling of wells, comprising an epitrochoidal rotary cylinder and a trirotor.
  • Figure 1 illustrates a well drilled with a downward bore followed by a horizontal bore, by means of which three reservoirs of oil or the like are accessed;
  • Figure 4 illustrates the use of multiple bores extending from a common downward bore
  • Figure 6 illustrates the use of multiple "J" shaped bores extending from a single vertical bore and a subsequent horizontal bore
  • Figure 9 illustrates a variation of the arrangement shown in figure 8.
  • Figures 15A & B illustrate a plan views of the wells shown in figures 14A & B, respectively;
  • Figure 17 shows a radial cross-section of an adjustable reamer/stabiliser blade with spherical cutter balls
  • Figure 20 shows an axial cross-section of a reamer/stabliser body
  • Figure 21 shows a radial cross-section of a caliper thrust unit
  • Figure 22 is an axial cross-section of the caliper thrust unit
  • Figure 23 is an axial cross-section of the caliper thrust unit caliper body and hydraulic drill collar piston valve block assembly
  • Figure 25 is a radial cross-section of the hydraulic drill collar piston valve assembly and cylinder body with telemetry unit controllers and valve control spool, telemetry unit controllers for dump valves;
  • Figure 26 is a radial cross-section of a telemetry control unit
  • Figure 28 shows an axial top section of a pivot ball joint
  • Figure 29 shows an axial cross-section of the trajectory control unit, cylinder body and piston with piston guide control tube and rod;
  • Figure 31 shows a radial cross-section of a fluid dump valve
  • Figure 33 shows a diagramatic drawing of a drilling assembly for directional/horizontal drilling
  • Figure 34 shows radial cross-sections of a telemetry unit controller
  • Figure 37 shows a diagramatic drawing of two single trajectory control units in a drilling assembly
  • Figure 38 shows a diagramatic drawing of a single trajectory control unit in a drilling system
  • Figure 39 shows radial cross-section of an orientation unit
  • Figure 41 shows a radial cross-section of a universal joint and output thrust shaft
  • Figure 42 shows a radial cross-section of a trajectory control unit and down-hole motor sealed bearing assembly (singie jend sub);
  • Figure 43 shows the main mechanism of the figure 42b arrangement to a larger scale
  • Figure 44 shows a radial cross-section of a compensating underreamer, hole opener/milling tool
  • Figure 46 illustrates the position of the trirotor in the epitrochoidal rotary chamber of the motor shown in figure 45;
  • Figure 1 to 13 inclusive show examples of the extraction of oil from an oil reservoir using the method of drilling into a an area of geothermal energy adjacent the oil reservoir.
  • geothermal energy has previously been used, eg for the generation of electricity, it has not previously been proposed to use geothermal energy to aid in the recovery of heavy oils and the like.
  • geothermal energy can be applied to a reservoir of oil.
  • One preferred method according to the present invention is to fracture the rock formations between the geothermal area and the oil reservoir.
  • This involves engineering to provide artificial permeability of the rock formations.
  • the engineering comprises the drilling of appropriately configured wells and the injection of a fluid, usually water under high pressure, to cause a network of fractures which will provide a pathway for the geothermai energy to be applied to the oil reservoir.
  • Another preferred method involves the drilling of a well through an area of geothermal energy and extending the well beyond the area of geothermal energy into the oil reservoir.
  • the well may be drilled through the oil reservoir and beyond the reservoir into an area of geothermal energy with subsequent blocking of the well above the fluid reservoir.
  • the well is blocked using a non-return valve, so as to permit the subsequent introduction downhole of any desired fluids.
  • Figure 2 illustrates a "U" shaped well in which a downward vertical bore 1 is followed by a short horizontal bore 4 and then an upward vertical bore 2.
  • Rock formations are indicated generally by reference 5 and reference 6 indicates a granite rock strata. High pressure water injected into the well bores 1,2 and 4 cause the granite to rupture, as indicated by reference 3.
  • Figure 3 illustrates a well which accesses two oil reservoirs, 4 and 5.
  • First a downward bore enters the first oii reservoir and the bore is then extended in a generally horizontal direction, at section 2, followed by a short upward bore 3 and finally another horizontal bore 7 which extends into reservoir 4.
  • Reference 6 indicates the layers of surface material.
  • Figure 4 illustrates the use of multiple bores extending from a common downward bore, 1.
  • the bottom of bore 1 branches into two bores which extend into different parts of a large oil reservoir 5.
  • One of the two bores, bore 2 is a generally horizontal bore.
  • the other of the two bores, bore 3 has a horizontal portion followed by an upward portion.
  • the upward portion extends into the second oil reservoir, 6.
  • a third bore, 4, extends into reservoir 6 from a side wall part way down the downward bore 1.
  • Reference 7 indicates the layers of surface material.
  • Figure 5 illustrates the use of multiple wells including in particular a well which passes through an area of geothermal energy and which subsequently extends into an oil reservoir.
  • Reference 8 indicates layers of surface material and reference 6 indicates a granite rock formation which has been artificially fractured, as indicated by reference 5.
  • the well extending through the geothermal area comprises a downward bore 1, an upward bore 3 and a generally horizontal bore 4. Bore 4 extends into the oil reservoir, 7.
  • Geothermal energy enters the well in the region of the artificial fractures 5 and passes along the well to reach the oil reservoir 7.
  • the vertical bore 1 may be blocked off as appropriate.
  • Geothermal energy entering the reservoir 7 reduces the viscosity of heavy crude oil in the reservoir and thus enables the recovery thereof via the three additional welis which are independently drilled from the surface into the reservoir 7.
  • Figure 6 illustrates the use of multiple "J" shaped bores 3 extending from a single vertical bore 1 and a subsequent horizontal bore 2.
  • References 5 and 6 indicate rock formations and reference 4 indicates the crude oil reservoir.
  • Figure 7 illustrates an arrangement of wells which might be provided so as to apply geothermal energy directly to a reservoir of heavy crude oil, so as to enable the recovery of oil which might not otherwise be possible.
  • a vertical bore 6 is drilled from the surface 1 through rock formations 2, 4 until an area of granite 5 is reached.
  • a generally horizontal bore 7 is drilled in the granite formation, or along the surface thereof .
  • the well is extended beyond the granite area by an upward bore 8 so as to reach a reservoir of heavy crude oil 3.
  • Within the reservoir the well continues as a generally horizontal bore 9, so as to increase dispersion of geothermal energy within the reservoir.
  • the granite lies above an area of geothermal energy and is artificially fractured by the injection of high pressure cold water into bores 1 and 7.
  • a separate well is used for extraction of the reduced viscosity oil.
  • the extraction well comprises a vertical bore 1 1 drilled from the surface 10 and an upward bore 13 and a horizontal bore 14 which extend from the bottom of the vertical bore 1 1 into the reservoir 3.
  • Figure 8 illustrates an arrangement in which separate wells are used to create the artificial fracturing of the granite rock formation and to form a pathway for the geothermal energy to enter the oil reservoir.
  • Three wells are shown in total, one being a cold water injection well for fracturing the granite and the other two being oil extraction wells which penetrate the oil reservoir 4.
  • Each of the three wells are drilled from the surface 1 through surface rock formations 2 and 3.
  • the cold water injection well comprises a bore 7 which extends down to the granite formation 5.
  • Each of the two wells entering the oil reservoir comprise a downward bore 9 continuing into at least one further bore.
  • the further bore is a generally horizontal bore 8 and in the other case multiple bores extend from the vertical bore.
  • the multiple bores comprise a "J" shaped bore and a generally horizontal bore 11, both of which access different parts of the oil reservoir.
  • the horizontal bore is drilled laterally from the vertical bore of the "J" and below that junction a downward bore 10 is drilled to access, via a subsequent horizontal bore 12, the artificially fractured granite.
  • FIG. 9 A variation of the arrangement shown in figure 8 is shown in figure 9.
  • a separate well, 7, is used for the formation of an artificial network of fractures, 6, in a layer of granite, 5.
  • An extensive reservoir, 3, of heavy crude oil is accessed by a plurality of wells.
  • One of the wells is shown as having dual horizontal bores extending within the reservoir from the bottom of a vertical bore 8.
  • Another well has a configuration which may be referred to as generally "S" shaped. That is, the well comprises a vertical bore 10 drilled from the surface 1 through surface layers of material 2 followed by a horizontal bore 1 1 which extends within the oil reservoir and finally a downward bore 12 which passes through various rock formations 4 below the oil reservoir so as to reach the fracture network 6 in the granite.
  • An additional horizontal bore 11 is drilled laterally from the base of vertical bore 10 and the well is blocked off, preferably using a non-return valve 13, just above the base of the vertical bore 10.
  • the well thus acts as a pathway for wide dispersal of geothermal energy within the oil reservoir.
  • Figure 10 illustrates a further arrangement in which a separate cold water injection well, 7, is used to create an artificial network of fractures, 6, in a granite formation 5.
  • a n additional side bore 8 is used to extend the area of artificial fracturing.
  • a single large diameter bore 9 is drilled from the surface 16 vertically into an extensive reservoir 3 of heavy crude oil. Multiple bores are drilled from the base of bore 9.
  • a "J" shaped bore 14 and a horizontal bore 13 access different parts of the reservoir.
  • Two “S” shaped bores 1 1 and 12 extend through rock formations 4 below the reservoir and access the artificial fracture network.
  • Crude oils below 20 degree -API gravity are usually considered to be heavy.
  • the lighter conventional crudes are often waterflooded to enhance recovery. The injection of water into the reservoir helps to maintain reservoir pressure and displace the oil toward the production wells.
  • waterflooding is most effective with light crude oil of 25 degree API gravity and higher and becomes progressively less effective with oils below 25 degree -API.
  • crudes of 20 degree and lower waterfloods are essentially ineffective and thermal recovery becomes necessary.
  • Very few thermal projects are successful in recovering oil of less than 10 degree API gravity.
  • Heavy crude oils have enough mobility that, given time, they will be producible through a well bore in response to thermal recovery methods. Tar sands contain immobile bitumen that will not flow into a well bore even under thermal stimulation.
  • Enhanced recovery processes are designed to reduce oil viscosity and capillarity by introducing into a reservoir other substances, such as carbon dioxide, polymers, solvents and micellar fluids in various combinations. Processes of this sort can further increase recovery from 40 to 80 percent of the in-place oil.
  • Thermal recovery methods are used to enhance the production of heavy crude oils, the recovery of which is impeded by viscous resistance to flow at reservoir temperatures. The recovery of the immobile oil in tar sands that will not flow even in response to thermal stimulation requires mining.
  • HDR hot rock
  • the primary technique for engineering these so-called hot rock (HDR) geothermal reservoirs utilises fluid pressure to open and propagate fractures from an inclined well, creating artificial permeability within a fracture network.
  • This hydraulicallv stimulated region is then connected to a second well to complete the underground system.
  • Heat is extracted by circulating water from the surface, down one well, through the fractured rock network, and up the second well.
  • the heated water passes through an appropriately designed power plant on the surface where, for instance, electricity or process steam is generated.
  • the cooled fluid is then reinjected to complete a closed loop cycle.
  • bitumen in tar sands can be recovered by surface mining methods.
  • a common method involving the use of steam to recover heavy oil is known as steam soak, or cyclic steam injection, it is essentially a well-bore stimulation technique in which steam generated in a boiler at the surface is injected into a production well for a number of weeks, after which the well is closed down for several days before being put back into production. In many cases there is a significant increase in output. It is sometimes economic to steam soak the well several times, even through heavy oil recovery using declines with each succeeding treatment. Steam soaks are economically effective only in thick permeable reservoirs in which vertical (gravity) drainage can occur.
  • the burning front is moved along by continuous air injection, in one variation of the in situ combustion process known as forward combustion, air is injected into a well so as to advance the burning front and heat and displace both the oil and water to surrounding produced wells.
  • forward combustion air is injected into a well so as to advance the burning front and heat and displace both the oil and water to surrounding produced wells.
  • a modified form of forward combustion incorporates the injection of cold water along with air to recover some of the heat remains behind the combustion front.
  • the air- water combination minimises the amount of air injected and the amount of in- place oil burned (to between 5 and 10 percent), in another variation of in situ combustion called reverse combustion, a short-term forward burn is initiated by air injection into a well that will eventually produce oil, after which the air injection is switched to adjacent wells. This process is used for recovering extremely viscous oil that will not move through a cold zone ahead of a forward-combustion front.
  • the actual quality or grade of the (HDR) resource at a specific location will control development costs, the primary parameter determining the local grade of the resource is the average temperature gradient or conversely the drilling depth required to reach a temperature suitable for the specified thermal enhanced oil recovery, either high pressure steam or hot water.
  • the primary parameter determining the local grade of the resource is the average temperature gradient or conversely the drilling depth required to reach a temperature suitable for the specified thermal enhanced oil recovery, either high pressure steam or hot water.
  • hot dry rock systems need only hot rocks at accessible depths in the earth's crust (HDR) resources range from low-grade regions having normal to near normal temperature gradients of 20° C to 40° C km to high grade regions with above-normal gradients greater than 40°C/km.
  • the lower-grade gradients is distributed more or less uniformly throughout the world. While the higher grade resources are found frequently within or near active natural geothermal areas.
  • the main cold water injection line into the (HDR) in the horizontal section is fractured along its length, cold water is injected into the well at pressure to hydraulically fracturing the (HDR) reservoir to produce super heated steam at very high temperatures above 300°C depending on the depth of the injection well.
  • a method to produce steam by (HDR) is by an injection well, and a second intersecting well into the fractured zone to produce well head steam, but obviously steam driven to the surface then fed by flow lines to various parts of the field for re-injection into the oil reservoir would be costly and would lose temperature very quickly, in the same way as produced steam by steam generation on the surface.
  • the (UCT) method quickly places the total heat from the steam/hot water directly into the oil reservoir driving the oil to the production wells in the pressurised closed HDR circulation loop.
  • the bore hole is drilled to target depth, then the water is pumped in to the well bore at pressure. This, combined with depth of head pressure in the well bore column of thousands of feet, makes the pressure at the well bottom far too great for the rocks to resist, so they simply fracture, explosive charges may be used to induce fractures.
  • the water is then forced up through the horizontal or lateral and up the "J" loop vertical of the well bore and comes out as superheated steam in the oil, tar sands, or, oil shale formation where the pressure and heat is so great that the oil is forced up through the production well bore system under pressure to the well heads to the separation and extraction plant where the cold water is then returned back down the injection well on a closed loop system.
  • High pressure hot water can be produced at about 130 degrees C and above at lower drilling depths, this would be ideal for hot water at pressures from 1,000 to 4,000 PSI depending on the formation with ultra high flow rates delivered by high pressure pumps to fully sweep the whole of the reservoir to ultimately improve the heat flow within the reservoir.
  • the process of high pressure reservoirs is derived from the capability of hydrocarbons to dissolve in water at near critical conditions so the pressure is above 3000 PSI and temperature above 300 degrees centigrade, and are efficient in densely fissured reservoirs for heavy and light oil, temperatures of 380 degrees centigrade to 480 degrees centigrade are required for oil shale recovery, so deeper well bores are required.
  • the coiled tubing carries an internal multicore electrical conduit for control purposes (MWD) improving drilling control, to improve the link between the coiled tubing unit for drilling (MWD), exploration, production and work-over wells from the smallest to the largest wellbores.
  • MWD multicore electrical conduit for control purposes
  • HDR geothermal concept is a proven method of producing high or low pressure steam and or hot water no obstacle has been found that would hold back its development, HDR reservoirs can be found in regions of previously impermeable crystalline rock with thermal/flow properties to allow for efficient heat/steam flows, in New Mexico (HDR) temperatures were as high as 232 degrees centigrade at under 4km depth, and to create even larger HDR reservoirs you would only need to pump cold water down for longer periods of time since the reservoir producing the steam volume is directly proportional to the amount of water injected in to the HDR reservoir, so one would only need to hydraulically fracture the reservoir at the outset.
  • HDR hot jointed crystalline rock
  • the producing steam well bore can either be plugged above the oil bearing zone or a none return valve placed down hole so as to allow for injection or other agents, and temperature recording equipment as shown in Fig. 9 item: 13 further side tracked horizontal wells can also be drilled from each vertical bore as item: 9 further steam injector horizontal bore can also be run from producing steam well shown in Fig. 9 item: 11, the scope to drill this type to produce (HDR) steam injected into an oil bearing reservoir from underneath has vast enhanced oil recovery potential and is the most economical way to produce oil from a reservoir and the only way in which to produce heavy oil offshore and above all is environmentally safe, with abundance of water.
  • HDR this type to produce
  • UCT steam or hot water is injected continuously from one well bore or more upwards from hot dry rocks (HDR) into the reservoir causing the viscosity of the oil to be reduced until it becomes mobile and can be displaced or produced by gravity drainage or vertical and horizontal in surrounding wells in a closed loop or open system.
  • the principal advantage is high pressure, volume and heat retention in the process of steam transmission to the oil reservoir.
  • the steam is driven upwards and forward into the reservoir, it is the only safe method to produce ultradeep oil bearing formations also with the possible aid of injecting high temperature super critical carbon dioxide CO 2 in to the (HDR) reservoir increasing recovering efficiency due to the action of CO 2 with oil or other types of stimulants and the resulting displacement and sweep efficiencies.
  • UCT high grade steam quality will enter into sand body to allow partial coking or in-situ sand consolidation without undue reservoir permeability damage.
  • the UCT method overcomes all of these problems as the total heat is placed where it is most needed in the oil bearing formation, there is no limitation to depth of oil production with this (UCT) method, this method also increases the amount of original oil in place (OOIP) to be produced as none is used to produce the steam normally, between one third and a quarter of all oil produced is used by the steam generators to produce the steam. This alone is a tremendous cost saving.
  • UCT original oil in place
  • Heavy oil deposits require the creation of fractures to induce artificial injectivity and significantly enlarge the interface between oil sands and injected fluid. This improves heat transfer by convection and conduction fractures created during the stimulation process are acting as natural channels for fluid and heat transfer into the reservoir.
  • the heated oil is driven to the producing wells by a complex array of displacement mechanisms including hot gas driven water displacement, hot water drive and steam or solvent assisted steam/hot water drive in a closed loop system.
  • the handling of the effluent water is part of the production cycle being re- injected into the cold water injection well down to the hot dry rocks, again this may possibly be treated first, in some cases before being re-cycled for produced steam, again injection rates can be high and pressure also. It is also possible to inject raw sewage into the (HDR) reservoir to produce steam in the same way.
  • Enhanced oil recovery and heavy crude, tar sands by (UCT) method of production development on offshore platforms are far cheaper to produce with less equipment needed on the platforms, and could be the only method to steam drive a reservoir offshore, this alone is a tremendous cost saving offshore, due to government regulations covering oil fired boilers.
  • Steam or hot water injection is the most advanced enhanced oil recovery technology for crude oil production, in some cases it may be necessary to use additives, like foaming agents to plug the steam filled zones so that it is driven into those parts of the reservoir that are still saturated with oil, in order to increase the efficiency it is necessary to use additives to decrease interfacial tension and mechanical completions to allow for production after steam breakthrough.
  • Steam injection quality is the key factor in steam zone formation, some higher quality will be problematical.
  • the effect of steam quality on oil recovery has a dual role, it determines heat input, and it also determines the two phase flow in the rock.
  • the quality of steam can be controlled in hot dry rock enhanced oil recovery (HDR/EOR) thermal ultradeep crude technology (UCT) by depth of hot dry rock reservoir, or with carbon dioxide CO 2 , with a super-critical carbon dioxide condition.
  • HDR/EOR hot dry rock enhanced oil recovery
  • UCT thermal ultradeep crude technology
  • the artificial lifting of crude oil from reservoirs with steam, hot water and water-flood creates constant changes that effect artificial lift design.
  • the lifted liquid volume increases while the percent of crude oil in the produced fluid decreases.
  • This increased expense and decreased return on capital will cause many producing wells to become marginal and some uneconomic, so the need to lift greater produced fluid volumes more efficiently is required.
  • the closed loop production system with the ultradeep crude technology - hot dry rock - enhanced oil recovery is very efficient for this purpose, with very high injection and produced fluid flow rates with no extra artificial lifting equipment, with no restrictions on depth for producing reservoir fluid, work-over well costs are minimal, efficiency is high, capital costs low and environmentally good with high capital return.
  • Extra heavy crude oil, tar sands, and oil sands are bitumens or petroleum like liquids or semi solid occurring naturally in porous and fractured media, oil impregnated rock, bitumens have viscosities greater than 10,000 mPas.
  • Crude oils have viscosities less than 10,000 mPas. These viscosities are gas free as measured and referenced to original reservoir temperature extra heavy crude oil have densities greater than 1,000 Kg per cubic metre (API gravities less than 10 degrees).
  • Heavy crude oils have densities from 934 to 1000 Kg per cubic measure (API gravities from 20 degrees to 10 degrees inclusive). These densities (API gravities) are referenced to 15.6 degrees C (60 degrees F) and the atmospheric pressure.
  • Crude oil with densities less than 934 Kg per cubic measure are classified as medium light, other crude oil below 20 degree API gravities are classified as heavy, extra heavy crude oil, tar sands, oil said and oil shale.
  • API gravities greater than 20 degrees are classified as medium light, other crude oil below 20 degree API gravities are classified as heavy, extra heavy crude oil, tar sands, oil said and oil shale.
  • These are world wide at depths as great as 14,000 feet in rocks of various lithologies and ages, in all climatic regions both on shore and offshore.
  • a vast amount of reservoirs that have been discovered have been plugged and abandoned or else never tested.
  • the amount of heavy crude oil also extra heavy crude oil, tar sands and oil shale resourced runs into many trillions of barrels.
  • Thermal processes are the predominant recovery methods the processes are primarily aimed towards a viscosity reduction and hence increase the mobility of this type of crude oil for production.
  • the technological advances in the (UCT) recovery methods if we take one oil field in California where 4000,000 barrel per day of heavy crude is produced in the field, to produce this, 100,000 of crude per day is required to run the steam generators, to produce the steam to recover the 4000,000 barrels, most of the oil produced in this reservoir ranges from 1 1 degrees to 15 degrees API. With the (UCT) method, the production would be 500,000 barrels per day, as no crude oil is required to run the steam generators. If we take 18 USD per barrel, this is a saving of 1,800,000 USD per day, so using the (HDR) (UCD) method is a very small price to pay for the increased production, and will also be extremely economical.
  • HDR HDR
  • the (UCT) method is expected to be used for either high pressure, low volume steam or low pressure high volume steam and high pressure volume steam.
  • the (UCT) method is expected to be used for either high pressure, low volume steam or low pressure high volume steam and high pressure volume steam.
  • the (HDR) method is expected to be used for either high pressure, low volume steam or low pressure high volume steam and high pressure volume steam.
  • the (HDR) method is expected to be used for either high pressure, low volume steam or low pressure high volume steam and high pressure volume steam.
  • the recovery factor using (UCT) method could include increase recovery rates of over 90% of the oil in place in the reservoir with this new innovative production technology (UCT) these include water, gas, solvent, surfactants and polymers.
  • the ideal way to produce the oil from the reservoir is to drill vertical, then horizontal under the formation, then vertical into the reservoir using the (UCT) drilling method with large bore hole as described in figure 6, with the use of "J" type well drilling, and using the horizontal well for collecting the oil by gravity drainage, then produced to the surface by the vertical well.
  • the drilling of "J" type wells can be of large diameter, the geology of all oil fields are a crystalline basement under sedimentary basins are constituted by metamorphic volcanic rocks and granite.
  • the very high cost of high pressure steam injection from the surface normally makes uneconomical to produce crude oil until now.
  • each underlying granite formation will vary in each location hot spots are found at a depth from 30 degrees C per kilometre depth and above to 70 degrees C km.
  • the right kind of low conductivity sediment layer with different crustal successions can effectively insulate the buried granite further enhancing its geothermal potential and obviating the need for excessively deep drilling.
  • the first step in the process of recovering the heat energy from this layer is to drill an injection well into the HDR formation which has very low permeability (e.g. granite) and sufficient temperature (preferably 240° to 330°C).
  • artificial fractures are created and held open in the rock formation using hydraulic stimulation techniques. Once the fracture system is created, one or more productions wells are drilled into the fracture zone so that they connect the fracture system to the surface.
  • the system for mining heat energy from hot dry rock (HDR) is essentially pollution free, as compared to conventional steam power generation plants, which create heat energy by burning fossil fuels.
  • the well configurations shown in figures 14 and 15 of the accompanying drawings are especially beneficial and are estimated to be capable of potentially reducing the cost of geothermal generation by as much as 80%.
  • a downhole thruster tool is extremely useful to drill long reach wells with coiled tubing or drill pipe together with special guidance tools, better downhole motors and drill bits to make the hole with light pressure.
  • coiled tubing you cannot rotate the string so normal methods do not allow for rotation of reamers/stabilisers and normal use of directional control unit overcomes all forms of directional well control from the surface, unlike the normal method where tripping the drill string from the hole is needed to replace directional control tools in the drill string.
  • This method opens up a completely new field of drilling practices together with cost saving in exploration and production drilling using coiled tubing drilling units or conventional drill pipe, coiled tubing can be tripped in very fast and out of the well with continuous fluid circulation.
  • bottom hole conditions can be monitored with through tubing electrical cables, kill weight drill fluids are not required to control the well.
  • Multiple bores can be drilled from the one bore, drilling can take place with the well under full pressure, back wrapping of the pipe (tube torquing) is overcome with the thrust calliper units drilling vertically, horizontal "U” and "J” type wells is now possible and even drilling horizontal from the vertical loop of the "J” type well.
  • the downhole positive displacement motor (PDM) is also very advantageous in a drilling system.
  • This invention employs trajectory control unit with the drilling motor and sealed bearings with stabiliser body which will propel itself by hydraulic thrusters, thrust calliper units anchored against hydraulic drill collars that grind the well bore.
  • the system eliminates the need for drill string weight on the drill bit and eliminates the limitations of compressively loading the lower part of the drill string to push the bit through the vertical and horizontal and the "U" type drilling.
  • Wells which are deviated to the horizontal mode, drilled laterally through a section of pay zone then deviated upwards, either to reach a second pay zone or extend higher into the pay zone or place injections well high in the reservoir, are ideal for drilling hot dry rock, geothermal injection and production of steam wells, also "J" type well for heavy oil production in combination with the hot rock drilling to inject into heavy oil and tar sand formations from the one bore hole.
  • the wells can be deviated through any range of vectors and are ideal for pressure depleted zones.
  • the system can drill radials of 2 ⁇ " inside diameter (I.D.) well bores to the largest size well-bore.
  • FIG. 8 Schematic drawing (figure 8) shows where a situation may be encountered, depth wise with either coiled tubing or conventional drill string where "J" type drilling may prove to be costly using present day tubing technology.
  • bore hole (7) will be cold water feed injector and bore hole (9) will be the steam production outlet line from the hot dry rocks, drilled from the top to intersect the HDR fractures.
  • the bore hole (9) will run through the oil bearing reservoir.
  • the casing will be cut just above the oil reservoir as shown at ( 10), by the milling or cutting method, the bore hole (9) will be side tracked into a horizontal bore hole (11), and the remainder of the production line (9), intersecting the HDR will then become bore hole (12), producing steam into the oil reservoir (4), the bore hole (8) is drilled horizontal into the oil reservoir and item (13) can be drilled in the "J" type configuration, well bore to be placed from underneath the reservoir.
  • Schematic drawing shows where a situation is encountered depth wise showing injector for cold water (item 7) drilled into fractured HDR reservoir and production extraction steam or hot water well (item 10) is drilled in the "S" type vertical or lateral from the surface and lateral or horizontal through the oil bearing foundation, then laterally o r* vertically down to intersect with the HDR reservoir. The well bore is then plugged back at item 13. Above the oil reservoir, more than one injector and/or producer can be drilled in each field if required with each well placed to a closed loop production system.
  • the schematic drawing shows figure 12 where high flow rates are required to be brought to the surface for separation and reinjection of the geofluid into the oil reservoir.
  • the schematic drawing shows figure 13 where a shaft/tunnels are drilled and horizontal twin wells are drilled with coiled tubing units.
  • the top well bore is for water/steam geofluid injection
  • the HDR production well is placed in the mine shaft floor with wellhead flow lines connected to the horizontal geofluid injector well bores, and the cold water/geofluid surface injector is drilled from the surface to the HDR reservoir.
  • Figure 6 is showing "J” type drilling with multiple vertical "J” type loops from the horizontal under the oil reservoir with multiple vertical upward well bores into the oil reservoir showing:
  • Figure 8 shows a diagrammatic view of the drill, and production of an oil reservoir and a hot dry rock steam injection method, showing:-
  • Figure 10 shows a diagrammatic view of the drilling and production of an oil reservoir and a hot dry rock steam injection method, showing:-
  • Figure 11 shows a diagrammatic view of the drilling and production of an oil reservoir and a hot dry rock steam injection method, showing: - 1. Shows vertical production bore hole. 2,3,4 & 5. Shows horizontal production screens.
  • HDR hot dry rocks
  • HDR hot dry rocks
  • HDR hot dry rock
  • (11) -Allows the use of HDR steam/hot water to be used for EOR methods when the geofluid is returned to the surface in conjunction with the drilling of UCT methods.
  • the ultra/high pressure fluid can be supplied from direct surface equipment, to the bit down-hole or converted to ultra/high pressure by other means, in the drilling bit (head) body downhole, to cut the rock/formation prior to the crushing/cutting action with the drilling head, to be used for enhanced oil recovery (EOR) methods in conjunction with hot dry rock (HDR) method ultradeep crude technology (UCT).
  • EOR enhanced oil recovery
  • HDR hot dry rock
  • Figure 17 shows a radial cross-section of an adjustable reamer/stabiliser blade with spherical cutter balls. 49. Shows blade body.
  • Figure 18 shows a radial cross-section of a reamer/stabiliser blade with cross cutting barrel rollers.
  • Figure 19 shows a radial cross-section of a reamer/stabiliser blade with vertical cutter rollers.
  • Figure 20 shows an axial cross-section of a reamer/stabliser body.
  • Another aspect of the present invention provides a thrust calliper tool.
  • This tool is a valuable aid in the drilling of multidirectional wells, such as those required to implement the first part of the invention.
  • An embodiment of the tool is shown in figure 21.
  • the tool body 41 is connected to the drill string at one end by the pin connection 31 and at the other end by a box connection 34.
  • Bore gripper blades 24 are carried by the main tool body and are, of course, arranged for radial movement with respect to the tool body. As shown, the blades have a generally trapezium shaped cross section with the shorter of the parallel sides being inner most. The inclined edges/surfaces rest on respective angle blocks 23,29. -As indicated in figure 22, four blades are located around the circumference of the tool and each is seated in a respective guide slot 25.
  • Each blade guide slot has a fixed angle block 29 at the end of the slot adjacent the pin connector 31 and a moveable, or thrust, angle block 23 at the other end of the slot.
  • the angle blocks each have an inclined surface, on which the respective inclined surfaces of the blade 2- * rest.
  • the trust angle block is capable of movement in the slot in the longitudinal direction of the tool body. It will be readily appreciated that such movement changes the distance between the angle blocks 23 and 29 and thus causes the inclined surfaces of the blade 24 to slide over the inclined surfaces of the angle blocks. This has the result of moving the blades radially with respect to the tool body.
  • the blades are retained in the tool body by means of pivotal links 26 by which they are attached to the angle blocks.
  • Each telemetry control unit comprises a piston 18 connected to the respective thrust angle block by a connecting rod.
  • a return spring 19 acts to return the angle block to the position in which the respective blade is fully retracted. Movement of the piston 18, and hence block 23 and blade 24, is controlled by an operator above ground by means of telemetry.
  • the thrust calliper provides thrust as well as calliper action.
  • the central portion of the tool can be thrust forward so as to exert forward thrust on a drill bit attached to the tool via pin connector 31.
  • the mechanism for achieving this thrust is located longitudinally behind the gripper blades 24 (to the left in figure 21) and is shown in more detail in figure 25.
  • Figure 25 also shows the detail of the telemetry control units used to control the movement of the calliper gripper blades 24.
  • a third thrust calliper tool may also be used in the drill string.
  • the calliper blades of the third tool can be used to grip the inner cylindrical surface of a bore liner.
  • the tool can be used to pull a liner along the bore behind the drill bit.
  • control units 1 and 2 These control units have a toggle and latch mechanism and control the flow of hydraulic fluid into chambers 40 and 33 respectively.
  • control units 50 and 53 which control movement of the calliper gripper blades are of essentially the same design as control units 1 and 2. The detail of one of these control units is shown in figure 26.
  • Hydraulic fluid within the drill string is used to operate the various mechanisms. .After use the fluid is dumped to the annulus between the drill string and the well bore.
  • the caliper thrust units hereafter referred to as CTU's consists of a caliper body employing the same trust angle blocks and fixed angle blocks together with centre angle blades as described in relation to the adjustable rotary roller reamer/stabiliser.
  • the caliper system consists of the main caliper body with either three (3) or four (4) oblong caliper housings machined into the caliper body, fitted into each caliper housing are the two (2) thrust angle blocks and fixed angle blocks together with the caliper blade well bore gripper segments, these are activated by a caliper thrust piston which is controlled by hydraulic pressure feed from the rear thrust collar valve control sub which is controlled by the forward thrust and return valve system within the centre valve assembly, this caliper thrust unit assembly simultaneously applies forward thrust to the hydraulic drill collar thrust piston exerting a forward motion on to three (3) or four (4) control pistons on the thrust angle caliper blocks which in turn forces out the caliper blades locking them into the well bore, and the return action of the caliper blade is again simultaneous, when no.
  • valve no. seven (7) is open, valve no. five (5) is closed, valve no. six (6) is open and valve no.
  • the pressure pulse then operates the toggle/latch assembly on no's nine (9) and ten (10) telemetry unit controllers, then shutting down the pumps to close both front and rear calipers (CTU) for tripping the drilling assembly out or into the well.
  • CTU front and rear calipers
  • the length of stroke of the (CTU) will be recorded on the measurement while drilling system (MWD), the information is fed to a computer when the maximum travel is obtained by the (CTU) recording complete depth record.
  • the cams and camshaft allows the valve sequences to be changed one set of calipers is retracted while the other set is locked to the well bore and simultaneously the (CTU) is thrust forward from the locked calipers adding weight to the drilling assembly and drill bit, while the other set of calipers is retracting.
  • the operational principle of the tool is by differential pressure across the tool, when each pair of valves are open to allow differential pressure into one side of the main valve body cylinder.
  • the telemetry unit controllers as used in the adjustable rotary roller reamer/stabiliser and thrust caliper units can also be used as a dump valve system as shown, which are activated at a pre-determined spring pressure set above the spring pressure of the other telemetry unit controllers, both of the dump valves will operate as a pair, either both in the closed position, allowing drilling fluid to leave chamber and feed port, which fees the chamber allowing the piston to return to the unlocked position, allowing the calipers to be retracted, this sequence is simultaneous on both front and rear calipers to allow tripping in and out of the well.
  • twin caliper eccentric system with eccentric stabilisers will allow the measurement while drilling system (MWD) to be placed as close as possible to the drill bit allowing complete trajectory control when used in the eccentric blade setting, it allows complete directional control with the use of two (2) adjustable reamer/stabiliser, one near bit and the other first string.
  • MWD measurement while drilling system
  • the pair of reamer/stabiliser can be full gauge together or under-gauge or one under-gauge and the other full gauge, allowing full directional control, for coiled tubing or conventional drill string drilling.
  • the twin caliper system fitted to either rotary drill pipe or coiled tubing allows thrust to the drilling assembly, the trajectory control unit for bit angle face and orientation unit may also be used if required, the adjustable rotary roller reamer/stabiliser gives a cutting and roiling action in the well bore reducing torque and drag and stopping slide drilling the complete system is operated on differential hydraulic pressure with all adjustments to the drilling assembly being performed down ⁇ hole purely by an increase in pressure by weight set control from the rig floor by the weight set accumulator fitted above the reamer/stabiliser and the trajectory control unit with orientation unit, by an increase in drilling pressure, the caliper system is working fully automatically with normal drilling pressure and can only be stopped by the increase of a pre-determined pressure to allow the four (4) telemetry unit controller dump valves to open, allowing tripping in and out of the well bore with the drill string.
  • the drilling assembly continues closed and mud pressure maintained the drilling assembly continues drilling and thrusting, making hole again, with the four (4) telemetry unit controller valves fitted in the thrust cali
  • a pair of thrust caliper units can also be fitted to the end of coiled tubing with drill pipe fitted to the thrust side between the drilling motor and trajectory control unit (TCU).
  • TCU trajectory control unit
  • Figure 21 shows a radial cross-section of a caliper thrust unit showing:-
  • cam shaft cylinder body (striker) (rear).
  • cam shaft cylinder body (striker) (front).
  • Figure 22 is an axial cross-section of the caliper thrust unit showing:-
  • Figure 25 is a radial cross-section of the hydraulic drill collar piston valve assembly and cylinder body with telemetry unit controllers and valve control spool, telemetry unit controllers for dump valves showing:-
  • connection control spool Shows connection control spool.
  • Figure 26 is a radial cross-section of a TUC with fluid valve spool type showing :-
  • control unit body front and rear.
  • Figure 27 shows a radial cross-section of a dual acting telemetry unit controller showing:-
  • TUC telemetry unit controller
  • Another aspect of the present invention provides a trajectory control unit and, preferably, a positive displacement drilling motor with at least one motor housing trajectory control unit.
  • Such tools are a valuable aid in the drilling of multidirectional wells, such as those required to implement the first part of the invention. Embodiments of this part of the invention are shown in figures 227 to 43 of the accompanying drawings.
  • This invention employs a double motor housing bend sub (telemetry unit controller) fitted to the bottom of the rotor stator motor housing, with the sealed bearing and output shaft incorporated in the near bit stabiliser housing and bottom pivot body sub.
  • This innovation opens up a complete new field for drilling practices, and will realise significant cost savings over present methods now in use.
  • Configurations of bottom hole assembly designs can vary, each configuration is designed to perform total directional control with the down-hole motor orientated in a particular direction by drill string rotation or by the orientation unit when used with coiled tubing, and to drill straight ahead by re-setting the double bend unit.
  • the straight position by the pre-determined pressure increase to the telemetry unit controllers (TUC's). This avoids totally dog legs within the well bore which can be used to plan and select a fully automated down-hole steerable assembly, which will drill a pre-determined well path.
  • the trajectory control units, telemetry unit controllers calibrated fluid chamber allows for 0.25 degree permitted build rate incruments put to 3 degrees, the two bends are featured in opposite directions which tilts the bits axis from the hole axis to enable a down-hole system to drill a curve when orientated in the right position. Drilling straight ahead requires a pressure change or pump on/off to go back to zero, this allows minimum bit offset reducing bit side loading.
  • a single bend motor housing can also be used to achieve a variety of build rates, this is ideal for re-entry work, two single trajectory control units, giving the drilling motor adjustment below and above the motor.
  • the reamer action on the first string stabiliser is employed to smooth the well bore, stabilise the assembly and straighten the well bore where kinks and dog legs are encountered. These unique features allow directional adjustments to be made from the rig floor while the drilling assembly is down-hole.
  • Extended bearing life is obtained by the sealed bearing assembly housed within the near bit stabiliser body and pivot sub, this allows all of the drilling fluid to be circulated through the bit for the maximum bit hydraulics and cleaning. Sealed bearing assemblies are lubricated by high temperature oil and fitted with high temperature seals. A dump sub valve is located at the top of the drilling motor to allow drilling fluid to by-pass the motor and fill the drill pipe while tripping into the hole, it also permits draining of the drill pipe when tripping out of the well or making a connection, closure occurs automatically with pump activation.
  • the universal joint assembly (flex joint) converts offset motion to the rotary drive shaft, effectively transferring power from the motor assembly. It is designed with a 1 to 2 or multi-helix configuration for high torque low speed output or low torque high speed output.
  • the trajectory control unit is controlled by a power section that employs a helical type screw sleeve and piston, round or square section with seals on the top and bottom of the piston fitted inside the main cylinder body with top and bottom housing subs, rotation of the piston is prevented by a guide rod and guide tube running through the piston and held in place by the top and bottom housing subs, the helical screw sleeve is fitted with eccentric cams, one facing in the opposite direction.
  • the telemetry unit controller is fitted into the bottom housing sub and is controlled by the guide tube running through the piston.
  • the unit is charged by means of a refill valve fitted in the side of the bottom housing sub allowing the bottom fluid outlet chamber to be pressurised and pushing the piston to the top start position.
  • the length of the helical screw and depth together with the fluid outlet chamber will determine the amount of rotations of the helical screw sleeve before the outlet fluid chamber requires recharging, rotation of the helical screw sleeve is allowed when fluid from the outlet fluid chamber is bled out of the telemetry control unit allowing the piston to travel downwards by drilling fluid entering into the top fluid inlet chamber via the non-return inlet valve, this in turn allows the rotation of the eccentric (bottom and top) trajectory crank cams to allow 0.25 degree angle change each time the telemetry control valve is operated by a pre-determined pressure increase from the rig floor.
  • This same system of piston drive power section is also used in the orientation unit, but with a bottom sealed bearing thrust sub and larger fluid chamber in the telemetry control valve allowing one (1) degree upwards directional orientation control.
  • the purpose of the trajectory control unit is to control the direction of drilling down-hole from the surface.
  • the main elements of the device are; (1) a pivot sub in the trajectory unit and a swivel thrust sub in the orien ation unit with zero to three degrees trajectory control and 360 degree directional orientation with one degree or more increments, (2) the piston drive shaft pressure assembly to produce the movement and (3) a telemetry unit controller to control the piston and rotary shaft movement by pressure impulses injected into the drilling fluid at the surface (pre ⁇ determined momentarily increase in drilling fluid pressure) by means of applying pressure to force the piston down, powering the drive sleeve is by direct drilling fluid pressure, the piston pressure is a constant proportion of the drilling fluid pressure.
  • the number of actuations possible before tripping to recharge the power section is determined by piston stroke and helical screw sleeve.
  • the telemetry unit controller is activated by a pressure pulse in the drilling fluid line and on actuation metres a defined volume from the power section, the required surface control feature thus results, correct sizing of the various elements, to achieve for example, one pulse equals 0.25 of trajectory change, it is designed to actuate within a window of drilling fluid pressure, for instance if drilling pressure was normally 1,600 psi the valve could be arranged to actuate in the trajectory control unit at 2,200 psi for trajectory change, after actuation the pressure would have to fall back to below say 1,900 psi before another actuation was possible, this would also activate the orientation unit, but this would not be significant, as to set directional orientation would be performed last at a pressure below trajectory change, say 2,000 psi, after actuation the pressure would have to fall back to 1,700 psi before another actuation was possible.
  • the reamer/stabiliser fitted with a telemetry unit controller with thrust piston and rod this unit consists of a valve housing body and actuator body, the valve housing body incorporates a thrust piston and rod held in place by a piston return spring, tension on the spring is adjustable by means of a spring adjuster, the piston and rod is activated by a toggle and latch fitted inside a toggle and latch housing that houses a toggle open latch plate, and a toggle close latch plate that is operated by an actuator piston fitted in the actuator body, when the toggle is on the toggle open latch the reamer/stabiliser is in full gauge position, when the toggle is in the close latch position the reamer/stabiliser is in the under gauge position, as shown in the toggle actuation diagram.
  • a pressure spring may also be fitted above the helical thrust piston inside the top fluid inlet chamber for continual pressure on the piston, and without the use of a non-return valve for drilling with two (2) phase fluids.
  • a single or multi helical screw or lobe type can be used in the piston and rotary sleeve.
  • the dual action telemetry unit controller allows tripping in and out of the well in the straight ahead mode.
  • the (TUC) is activated by pump pressure when the pumps are on.
  • the metering piston in the (TUC) travels forward and allows rotation of the rotor sleeve allowing trajectory control bit angle face as the piston displaces fluid from the bottom chamber through the (TUC), when the pumps are shut off the metering piston returns and displaces fluid from the bottom chamber allowing the piston to travel downwards rotating the rotor sleeve allowing the bit angle face to return to the straight ahead position for tripping out of the well.
  • the trajectory control unit and orientation control unit can also be controlled by pulses within the drilling fluid to activate the telemetry unit controller (TUC) with pulse control unit fitted.
  • the cam action in the fork can be set for the dual action telemetry valve to be used to change angle with pump on and pump off positions, ie. pump off straight ahead 0 degree, pump on 1 degree angle (drill), pump off 1.5 degree angle, pump on 2 degree angle (drill), pump off 2.5 degree angle, pump on 3 degree angle (drill), pump off 0 degree angle well bore to drill straight ahead when down-hole, the first position would be changed by the setting of the can face design, this will allow angle face changes by pump on and off without any hydraulic pressure increase or pulse changes down-hole, a drilling record will need to be recorded on the amount of pump stopping and starting to determine bit angle face.
  • the size of the metering chamber determines the amount of piston travel and rotation of the drive sleeve and degree angle of bend.
  • FIG 27 shows a radial cross-section of a trajectory control unit (TCU), and down ⁇ hole motor sealed bearing assembly (double bend sub or single).
  • TCU trajectory control unit
  • TCU down ⁇ hole motor sealed bearing assembly
  • TUC inlet port telemetry unit controller
  • TUC telemetry unit controller
  • Figure 27a shows a sub-assembly, the detail of which is essentially shown in figure 34.
  • Figure 28 shows an axial top section of item 8 pivot ball joint with bore and top fork.
  • CAM eccentric trajectory crank
  • Figure 29 shows an axial cross-section of the trajectory control unit, cylinder body and piston with piston guide control tube and rod.
  • Figure 32 shows a radial cross-section of a down-hole drilling motor.
  • stator rubber type compound 1 - 2 or multi-helix.
  • TCU trajectory control unit
  • Figure 34 shows radial cross-sections of a telemetry unit controller (TUC) (fluid metering type).
  • TUC telemetry unit controller
  • TCU trajectory control unit
  • Figure 38 shows a diagramatic drawing of a single trajectory control unit in a drilling system.
  • TCU trajectory control unit
  • Figure 39 shows radial cross-section of an orientation unit.
  • TUC Telemetry unit controller
  • FIG 40 shows a diagramatic view of a twin bend housing assembly trajectory control unit (TCU) as per figure 27.
  • TCU twin bend housing assembly trajectory control unit
  • TCU twin bend trajectory control unit
  • Figure 41 shows a radial cross-section of a universal joint and output thrust shaft.
  • TCU's adjustable near bit stabiliser with trajectory control units
  • either one or more trajectory control units can be used predicting how a given bottom hole assembly (BHA) will perform by contact points with the bore hole wall, the two stabilisers and the bit serve as tangency points that define a constant radius arc along which the assembly will drill when orientated.
  • Hole curvature, or design build rate can be adjusted by varying the trajectory control unit angle, the variable diameter and the placement of the first string reamer/stabiliser.
  • build rates can be fine tuned by telemetry control down-hole to the trajectory control unit for precise directional control.
  • the transmitter unit consists of a single chip microcomputer unit and a power amplifier, two switches, on/off, activate the microcomputer and solenoid valves, operate the pressure pulse valve.
  • the epitrochoidal rotary cylinder and trirotor is an ideal method when used as a drilling mud motor which has advantages over the normal rotor/stator type motor due to the absence of the rubber compound type stator/rotor which will not perform in temperatures in excess of 350 degrees F.
  • As the epitrochoidal rotor chamber/trirotor stator has no rubber compound sealing arrangement.
  • the epitrochoidal rotor cylinder is rotated round the fixed thrust bearing sub by the fixed drive pinion gear shaft connected to the fixed thrust bearing sub by a non rotating constant velocity flexible joint to allow orbital movement of the outer epitrochoidal casing rotor by the force of drilling fluid pumped under pressure through the peripheral two inlet ports machined into the sides of the epitrochoidal rotor cylinder, rotating the trirotor and discharging the drilling fluid through the peripheral two outlet ports.
  • Figure 45 shows epitrochoidal rotor/trirotor stator positive displacement mud drilling motor with fixed orbital trirotor stator and rotary epitrochoidal outer rotor with rotary stabiliser showing:-
  • Another aspect of the present invention provides a Ulatalobe Cavity Trirotor Displacement Pump/Motor.
  • This tool is a valuable aid in the drilling of multidirectional wells, such as those required to implement the first part of the invention. -An embodiment of the tool is shown in figure 47 of the accompanying drawings.
  • This part of the invention provides an alternative outer pump casing, with intemal helix, a fixed female external helix outer stator with intemal helix and a fixed male inner external helix fitted to the pump end casing at one end and the central male external helix/female intemal helix rotor driye head fitted within the two stators by a constant velocity flexible connecting joint.
  • the use of one male/female cylindrical rotor, spinning inside the outer female stator and inside the central male stator ensures that cavities are formed and progress in an upward or downward direction, depending upon the rotation of the pump or motor. Fluid enters the cavities and is driven through the rotors, stators/stator.
  • the lobes on the rotors/stators form cavities between the cylindrical multi-helix male/female rotor and the male/female stators as the cylindrical male/female rotor turns about its eccentric rotation around the outer male stator and also eccentric rotation inside the female stator, fluid enters and leaves the central male/female rotor stator cavities through the inner and outer feeder pathways on the cylindrical male/female rotor ends, or by direct feed into the cavities in pumps or motors when the bearings are not used on the outlet side of the inner male stator and inlet side of the drive head male and female rotor, but still retaining the flow pathways on the drive head shaft rotor end.
  • Multi phase fluids can also be pumped by the use of twin outer left hand and right hand female internal helix stators allowing for centre fluid chamber and outer fluid feed chambers, the centre male left hand and right hand exterior helix stator with centre flow recess, the male stator is fixed to the pump casing at the bottom end and held in position in the main rotor by bearings so that the rotor and the flexible joint rotate around the inner male fixed stator.
  • the only moving part is the male/female intemal helix cylindrical rotor with left hand and right hand helix, with out fluid pathways to feed the central rotors, stators through the cavities formed by the contra rotating helix allowing fluid to be driven to the centre outlet pump chamber.
  • the cylindrical male/female contra rotating helix rotor has central fluid pathways to allow the fluid to enter the centre outlet chamber with the fluid from the outer male rotors/stators, the outer cylindrical rotors and fixed male stators with one less lobe than the outer stator and inner rotor both move around the inside of the stator/rotors.
  • This combined geometry sequentially seals the flow chambers through which the fluid moves axially, the configuration of the rotors and stators conra rotating act as integral opposing reducing gears and opposing power generation units which delivers high pump volume with high pressure by the contra rotating multi-helix rotors and stators.
  • the ultralobe cavity trirotor positive displacement pump has only one moving part, that of the male/female multi-helix drive head rotor with male extemal helix rotor and female intemal helix rotor, the outer female intemal helix stators and the fixed male extemal helix stator.
  • the female and male stators can be precision moulded from durable corrosion resistant synthetic elastomer which is permanently bonded to a steel housing.
  • the drive head cylindrical rotor intemal helix is precision moulded and permanently bonded to the drive head rotor but other methods may by used by those skilled in the art, with the extemal helix bonded to the central male fixed stator.
  • This type of design cannot gas lock so pumping free gas is ideal for this system. It is also ideal for pumping in adverse conditions such as sand, gypsum, salt, parafin, wax, gas and high viscosity crude.
  • Multi-helix or 1/2 lobe rotors/stators are covered within the invention.
  • the male stator and female stator is fitted with a constant velocity flexible connecting rod assembly.
  • the male/female rotor/stator can also be contra rotating.
  • Figure 47 shows a radial cross-section of a multiphase flow type ultralobe cavity trirotor pump showing:-

Abstract

Un premier aspect de l'invention concerne un procédé d'extraction d'un fluide d'un réservoir (7) à l'aide de l'énergie géothermique. Ce procédé consiste de préférence à forer un puits (1) dans une zone disposant d'énergie géothermique (6) pour permettre la libération de cette énergie dans le réservoir de fluide (7). On décrit une configuration de puits particulièrement avantageuse pour l'extraction d'énergie géothermique en général. En mettant en ÷uvre le premier aspect de cette invention, il peut se révéler particulièrement bénéfique de pouvoir forer des puits horizontaux et/ou montants à partir d'un puits conventionnel descendant. D'autres aspects de l'invention concernent l'appareil qui permet de forer de tels puits. Ces outils comprennent un trépan aléseur/stabilisateur réglable, un dispositif de mesure de poussée, un moteur de forage volumétrique, un circuit de commande de trajectoire, un moteur/pompe volumétrique trirotor à cavités ultralobes, un moteur de forage à boue trirotor et un trépan élargisseur de compensation.
PCT/GB1994/000515 1993-03-17 1994-03-15 Ameliorations concernant les forages et l'extraction de fluides WO1994021889A2 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU62147/94A AU6214794A (en) 1993-03-17 1994-03-15 Improvements in or relating to drilling and to the extraction of fluids

Applications Claiming Priority (8)

Application Number Priority Date Filing Date Title
GB939305532A GB9305532D0 (en) 1992-10-12 1993-03-17 Ultralobe cavity trirotor pumps and motors for rotary drilling tolls
GB9305532.5 1993-03-17
GB939317690A GB9317690D0 (en) 1993-03-17 1993-08-25 Trajectory control positive displacement drilling motors
GB9317690.7 1993-08-25
GB9319994.1 1993-09-28
GB939319994A GB9319994D0 (en) 1993-09-28 1993-09-28 Trajectorey control positivo displacement drilling motors
GB939321003A GB9321003D0 (en) 1993-10-12 1993-10-12 Ultralock torque couplings
GB9321003.7 1993-10-12

Publications (2)

Publication Number Publication Date
WO1994021889A2 true WO1994021889A2 (fr) 1994-09-29
WO1994021889A3 WO1994021889A3 (fr) 1994-12-08

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CA (1) CA2158637A1 (fr)
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WO1996003566A2 (fr) * 1994-07-26 1996-02-08 John North Perfectionnements se rapporant aux forages pratiques a l'aide d'un systeme de forage par ecaillage thermique comprenant une chambre de combustion ainsi qu'un systeme de separation gaz/liquide par hydrocyclone ou par generateur a vortex
WO1998004807A1 (fr) * 1996-07-26 1998-02-05 Amoco Corporation Procede d'extraction a la vapeur dans un puits unique
WO1998049424A1 (fr) * 1997-04-28 1998-11-05 Shell Internationale Research Maatschappij B.V. Utilisation de materiel dans un systeme de puits
EP0888489A1 (fr) * 1996-03-20 1999-01-07 Mobil Oil Corporation Procede de recuperation d'hydrocarbures au moyen de puits de production inverses
US6000471A (en) * 1995-01-27 1999-12-14 Langset; Einar Hole in the ground for transfer of geothermal energy to an energy-carrying liquid and a method for production of the hole
WO2000031376A2 (fr) * 1998-11-20 2000-06-02 Cdx Gas, Llc Procede et systeme d'acces a des couches de depots souterrains a partir de la surface
US6267172B1 (en) 2000-02-15 2001-07-31 Mcclung, Iii Guy L. Heat exchange systems
WO2001092684A1 (fr) * 2000-06-01 2001-12-06 Pancanadian Petroleum Limited Appareil et procede pour puits de production
EP1048820A3 (fr) * 1999-04-29 2002-07-24 FlowTex Technologie GmbH & Co. KG Procédé pour l'exploitation de l'énergie géothermique et dispositif d'échange de chaleur à cet effet
US6591903B2 (en) 2001-12-06 2003-07-15 Eog Resources Inc. Method of recovery of hydrocarbons from low pressure formations
EP1339939A1 (fr) * 2000-10-12 2003-09-03 Transco Manufacturing Australia Pty Ltd Outil de forage utilise dans des applications de forage horizontales
WO2005003509A1 (fr) * 2003-06-30 2005-01-13 Petroleo Brasileiro S A-Petrobras Procede de fabrication d'un puits longue distance destine a la production, au transport, au stockage et a l'exploitation de couches et fluides mineraux
AU2001295249B2 (en) * 2000-10-12 2006-09-21 Transco Manufacturing Australia Pty Ltd A drilling tool used in horizontal drilling applications
WO2006130652A2 (fr) * 2005-05-31 2006-12-07 Cdx Gas, Llc Systeme de puits de forage a cavite
FR2962195A1 (fr) * 2010-06-30 2012-01-06 Marie Francois Herve Berguerand Dispositif de recuperation de chaleur geothermique de moyenne et haute energie, comportant un circuit primaire de fluide frigorigene, pour la generation d'electricite, le chauffage ou la cogeneration
US8381810B2 (en) 2009-09-24 2013-02-26 Conocophillips Company Fishbone well configuration for in situ combustion
CN103512254A (zh) * 2012-06-29 2014-01-15 韩国地质资源研究院 用于增强型地热系统的深井系统及其钻井方法
US8657038B2 (en) 2009-07-13 2014-02-25 Baker Hughes Incorporated Expandable reamer apparatus including stabilizers
EP2313708A4 (fr) * 2008-06-13 2014-04-09 Michael J Parrella Systeme et procede de capture de chaleur geothermique provenant de l'interieur d'un puits fore afin de generer de l'electricite
WO2014064485A1 (fr) * 2012-10-22 2014-05-01 Halliburton Energy Services, Inc. Améliorations apportées ou se rapportant à des outils de forage
EP2811109A1 (fr) * 2013-06-04 2014-12-10 Kongsberg Devotek AS Procédé pour établir un puits
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
CN110791277A (zh) * 2019-11-14 2020-02-14 西安石油大学 一种油田用不返排可转化为驱油剂的压裂液及其制备方法
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
CN113431542A (zh) * 2020-07-27 2021-09-24 中国石油化工股份有限公司 水平井压裂裂缝干扰强度的计算方法
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins
WO2022055947A1 (fr) * 2020-09-08 2022-03-17 Saudi Arabian Oil Company Élargissement de puits de forage
CN114961668A (zh) * 2022-05-18 2022-08-30 太原理工大学 一种裂隙型干热岩储层双斜井分段调控强化采热方法
US11525186B2 (en) 2019-06-11 2022-12-13 Ecolab Usa Inc. Corrosion inhibitor formulation for geothermal reinjection well
WO2023012442A1 (fr) * 2021-08-03 2023-02-09 Reme, Llc Vanne d'isolement de piston pour outil rotatif orientable
US11624265B1 (en) 2021-11-12 2023-04-11 Saudi Arabian Oil Company Cutting pipes in wellbores using downhole autonomous jet cutting tools

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Cited By (43)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO1996003566A3 (fr) * 1994-07-26 1996-05-09 John North Perfectionnements se rapporant aux forages pratiques a l'aide d'un systeme de forage par ecaillage thermique comprenant une chambre de combustion ainsi qu'un systeme de separation gaz/liquide par hydrocyclone ou par generateur a vortex
WO1996003566A2 (fr) * 1994-07-26 1996-02-08 John North Perfectionnements se rapporant aux forages pratiques a l'aide d'un systeme de forage par ecaillage thermique comprenant une chambre de combustion ainsi qu'un systeme de separation gaz/liquide par hydrocyclone ou par generateur a vortex
US6000471A (en) * 1995-01-27 1999-12-14 Langset; Einar Hole in the ground for transfer of geothermal energy to an energy-carrying liquid and a method for production of the hole
EP0888489A4 (fr) * 1996-03-20 2000-10-18 Mobil Oil Corp Procede de recuperation d'hydrocarbures au moyen de puits de production inverses
EP0888489A1 (fr) * 1996-03-20 1999-01-07 Mobil Oil Corporation Procede de recuperation d'hydrocarbures au moyen de puits de production inverses
WO1998004807A1 (fr) * 1996-07-26 1998-02-05 Amoco Corporation Procede d'extraction a la vapeur dans un puits unique
WO1998049424A1 (fr) * 1997-04-28 1998-11-05 Shell Internationale Research Maatschappij B.V. Utilisation de materiel dans un systeme de puits
WO2000031376A3 (fr) * 1998-11-20 2001-01-04 Cdx Gas Llc Procede et systeme d'acces a des couches de depots souterrains a partir de la surface
WO2000031376A2 (fr) * 1998-11-20 2000-06-02 Cdx Gas, Llc Procede et systeme d'acces a des couches de depots souterrains a partir de la surface
EP1048820A3 (fr) * 1999-04-29 2002-07-24 FlowTex Technologie GmbH & Co. KG Procédé pour l'exploitation de l'énergie géothermique et dispositif d'échange de chaleur à cet effet
US6267172B1 (en) 2000-02-15 2001-07-31 Mcclung, Iii Guy L. Heat exchange systems
US6338381B1 (en) 2000-02-15 2002-01-15 Mcclung, Iii Guy L. Heat exchange systems
WO2001092684A1 (fr) * 2000-06-01 2001-12-06 Pancanadian Petroleum Limited Appareil et procede pour puits de production
US6454010B1 (en) 2000-06-01 2002-09-24 Pan Canadian Petroleum Limited Well production apparatus and method
EP1339939A1 (fr) * 2000-10-12 2003-09-03 Transco Manufacturing Australia Pty Ltd Outil de forage utilise dans des applications de forage horizontales
EP1339939A4 (fr) * 2000-10-12 2005-04-06 Transco Mfg Australia Pty Ltd Outil de forage utilise dans des applications de forage horizontales
AU2001295249B2 (en) * 2000-10-12 2006-09-21 Transco Manufacturing Australia Pty Ltd A drilling tool used in horizontal drilling applications
US6591903B2 (en) 2001-12-06 2003-07-15 Eog Resources Inc. Method of recovery of hydrocarbons from low pressure formations
WO2005003509A1 (fr) * 2003-06-30 2005-01-13 Petroleo Brasileiro S A-Petrobras Procede de fabrication d'un puits longue distance destine a la production, au transport, au stockage et a l'exploitation de couches et fluides mineraux
WO2006130652A3 (fr) * 2005-05-31 2007-04-05 Cdx Gas Llc Systeme de puits de forage a cavite
WO2006130652A2 (fr) * 2005-05-31 2006-12-07 Cdx Gas, Llc Systeme de puits de forage a cavite
EP2313708A4 (fr) * 2008-06-13 2014-04-09 Michael J Parrella Systeme et procede de capture de chaleur geothermique provenant de l'interieur d'un puits fore afin de generer de l'electricite
US8657038B2 (en) 2009-07-13 2014-02-25 Baker Hughes Incorporated Expandable reamer apparatus including stabilizers
US8381810B2 (en) 2009-09-24 2013-02-26 Conocophillips Company Fishbone well configuration for in situ combustion
FR2962195A1 (fr) * 2010-06-30 2012-01-06 Marie Francois Herve Berguerand Dispositif de recuperation de chaleur geothermique de moyenne et haute energie, comportant un circuit primaire de fluide frigorigene, pour la generation d'electricite, le chauffage ou la cogeneration
CN103512254A (zh) * 2012-06-29 2014-01-15 韩国地质资源研究院 用于增强型地热系统的深井系统及其钻井方法
CN103512254B (zh) * 2012-06-29 2016-02-03 韩国地质资源研究院 用于增强型地热系统的深井系统及其钻井方法
WO2014064485A1 (fr) * 2012-10-22 2014-05-01 Halliburton Energy Services, Inc. Améliorations apportées ou se rapportant à des outils de forage
US8807246B2 (en) 2012-10-22 2014-08-19 Halliburton Energy Services, Inc. Downhole tool and control module
EP2811109A1 (fr) * 2013-06-04 2014-12-10 Kongsberg Devotek AS Procédé pour établir un puits
US11142681B2 (en) 2017-06-29 2021-10-12 Exxonmobil Upstream Research Company Chasing solvent for enhanced recovery processes
US10487636B2 (en) 2017-07-27 2019-11-26 Exxonmobil Upstream Research Company Enhanced methods for recovering viscous hydrocarbons from a subterranean formation as a follow-up to thermal recovery processes
US11002123B2 (en) 2017-08-31 2021-05-11 Exxonmobil Upstream Research Company Thermal recovery methods for recovering viscous hydrocarbons from a subterranean formation
US11261725B2 (en) 2017-10-24 2022-03-01 Exxonmobil Upstream Research Company Systems and methods for estimating and controlling liquid level using periodic shut-ins
US11525186B2 (en) 2019-06-11 2022-12-13 Ecolab Usa Inc. Corrosion inhibitor formulation for geothermal reinjection well
CN110791277A (zh) * 2019-11-14 2020-02-14 西安石油大学 一种油田用不返排可转化为驱油剂的压裂液及其制备方法
CN113431542A (zh) * 2020-07-27 2021-09-24 中国石油化工股份有限公司 水平井压裂裂缝干扰强度的计算方法
WO2022055947A1 (fr) * 2020-09-08 2022-03-17 Saudi Arabian Oil Company Élargissement de puits de forage
US11428049B2 (en) 2020-09-08 2022-08-30 Saudi Arabian Oil Company Wellbore underreaming
WO2023012442A1 (fr) * 2021-08-03 2023-02-09 Reme, Llc Vanne d'isolement de piston pour outil rotatif orientable
US11624265B1 (en) 2021-11-12 2023-04-11 Saudi Arabian Oil Company Cutting pipes in wellbores using downhole autonomous jet cutting tools
CN114961668A (zh) * 2022-05-18 2022-08-30 太原理工大学 一种裂隙型干热岩储层双斜井分段调控强化采热方法
CN114961668B (zh) * 2022-05-18 2023-12-29 太原理工大学 一种裂隙型干热岩储层双斜井分段调控强化采热方法

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