EA019369B1 - System and method for controlling a drilling system for drilling a borehole in an earth formation - Google Patents

Abstract

A method for using dynamic motion of a drilling system in a borehole being drilled or cored in an earth formation by the drilling system, the drilling system comprising a drill bit and a drill-string, to control the drilling system, comprising: controlling dynamic interactions between a section of the drilling system and an inner surface of said borehole; and using the controlled dynamic interactions between the section of the drilling system and the inner surface of said borehole to control the drilling system and using a drill collar or gauge pad non-concentrically coupled with the drilling system to dynamically interact with the inner surface.

Description

This invention generally relates to a method and system for controlling a drilling system for drilling a wellbore in a geological formation. More specifically, but not by way of limitation, in one embodiment of the present invention, a system and method for controlling interactions between a borehole drilling system for a borehole and a borehole surface for providing directional drilling of a borehole system for directional drilling of a borehole through a geological formation is provided. In some aspects of the present invention, the drilling system can be controlled to ensure that the wellbore reaches the project site.

In another embodiment of the present invention, it is possible to record data regarding the functioning of the drilling system while drilling a borehole, and to control the interactions between the drilling system of a drilling borehole and the surface of the borehole, responding to the measured data to provide control over the operation of the drilling systems. In some aspects, interactions between the drilling system and the surface can be controlled to control the interaction of the drill bit with the geological formation.

In industry practice, directional drilling of a wellbore through a geological formation or drilling for coring in subterranean formations is often necessary so that the wellbore and / or coring can bypass and / or pass through reservoirs and / or reservoirs in the reservoir to achieve a given goal in the formation and / or the like When drilling a wellbore or drilling for coring in underground formations, in some cases it is necessary to be able to change and control the direction of drilling, for example, to direct the wellbore to the design goal or to regulate the horizontal direction in the hydrocarbon-containing area after reaching the design object. It may also be necessary to adjust the deviation from the desired direction when drilling a straight borehole or to control the direction of the wellbore in order to avoid obstacles.

In the oil and gas industry, for example, a wellbore can be drilled to open a specific subterranean formation at a specific location. In some drilling processes, in order to complete the required wellbore, the drilling path through the geological formation may be pre-planned and the drilling system may be controlled to match the drilling path. In other processes, or in combination with the previous process, the goal for the wellbore can be determined and the progress of drilling the wellbore in the geological formation during the drilling can be monitored and measures can be taken to ensure that the wellbore achieves the design goal. In addition to this, the operation of the drilling system can be controlled to ensure economical drilling, which may include drilling with the most rapid penetration of the geological formation, drilling with reduced wear of the bit, drilling to achieve optimal penetration through the geological formation and optimal wear of the bit and / or the like.

One aspect of the drilling process is called directional drilling. Directional drilling is the deliberate deviation of a wellbore from a naturally selected path. In other words, directional drilling is the guidance of the drill string, such that the drill string moves in the desired direction.

Directional drilling is preferred in offshore drilling because it enables the drilling of multiple wells from one drilling platform. Directional drilling also provides horizontal drilling through the reservoir. Horizontal drilling provides the creation of a segment of the wellbore of increased length passing through the reservoir, which increases the productivity of the well.

A directional drilling system can also be used in vertical drilling operations. Often, the drill bit deviates from the projected drilling path due to the unpredictable nature of the formations and / or the changing forces that the drill bit experiences. When such a deviation occurs, a directional drilling system can be used to return the drill bit to the trajectory.

The monitoring process for directional drilling of a borehole may include determining the location of the drill bit in the geological formation, determining the orientation of the drill bit in the geological formation, determining the axial load on the drill bit of the drilling system, determining the drilling speed through the geological formation, determining the properties of the drilling geological formation, determination of the properties of the subterranean formation surrounding the drill bit; prediction of some properties of the formations in front of the drill bit , seismic analysis of the geological formation, determination of reservoir properties, etc. near the drill bit, measuring pressure, temperature, and / or the like. in the wellbore and / or surrounded by the wellbore and / or the like. In any process for directional drilling of the wellbore, if the design path is followed, the drilling process and / or drilling conditions and / or the like are monitored, it is necessary to be able to guide the drilling system.

The forces exerted on the drill bit during the drilling operation include gravity, torque developed by the bit, end load applied to the bit, and bending

- 1 019369 moment from the drilling assembly. These efforts, together with the type of drilling layer and the inclination of the layer to the wellbore, can create a complex interacting system of forces during drilling.

The drilling system may be a rotary drilling system in which a downhole assembly including a drill bit is connected to a drill string that can be driven / rotated from a drilling platform. In a rotary drilling system, directional drilling of a wellbore can be achieved by changing factors, such as axial load on the bit, rotational speed, etc.

For rotary drilling, known directional drilling methods include the use of rotary controlled systems (RUS). In RUS, the drill string is rotated from the surface and the bottom-hole devices drill with the drill bit in the required direction. Rotation of the drill string significantly reduces the possibility of jamming or sticking of the drill string while drilling.

Rotary guided drilling systems for directional drilling of wellbores through the earth’s stratum can generally be classified with separation of the entire assembly from the well axis and the bit positioning system into systems. In the bit positioning system, the axis of rotation of the drill bit deviates from the local axis of the layout of the bottom of the drill string (BHA) in the general direction of the new borehole. The borehole is carried out according to the standard three-point geometry formed by the upper and lower points of contact of the centralizer with rigid blades and the drill bit. The angle of deviation of the axis of the drill bit in conjunction with a finite distance between the drill bit and the lower centralizer with rigid blades gives the non-collinearity condition required to create a curve. There are many ways in which this can be achieved, including a fixed bend at the layout point of the bottom of the drill string near the lower centralizer with rigid blades or a bend of the drive shaft of the drill bit distributed between the upper and lower centralizer with rigid blades.

The positioning of the bit may include the use of a downhole hydraulic motor to rotate the drill bit, and the engine and drill bit mounted on the drill string, which includes bending at an angle. In such a system, the drill bit can be connected to the engine by a swivel or deflecting mechanism / link, a curved sub or the like, while the drill bit can be tilted relative to the engine. When a change in the direction of drilling is necessary, the rotation of the drill string can be stopped and the bit can be installed in the wellbore using the downhole hydraulic motor in the desired direction, and rotation of the drill bit can begin drilling in the required direction. In such a device, the direction of drilling depends on the angular position of the drill string.

In its idealized form, in a system with positioning a bit, the drill bit does not need to perform lateral cutting, since the axis of the bit constantly rotates in the direction of the curved borehole. Examples of rotary controlled systems with bit positioning and principles of their operation are described in US Patent Application Publications No. 2002/0011359; 2001/0052428 and US Patent No. 6394193; 6364034; 6244361; 6,158,529; 6092610 and 5113953, all incorporated herein by reference.

Systems for repelling the entire arrangement from the axis of the well and methods utilize a force against the wall of the wellbore to bend the drill string and / or direct lateral force on the drill bit to be drilled in the preferred direction. In a rotary controlled system of repelling the entire assembly from the axis of the well, the required condition of non-collinearity is achieved by applying a force mechanism that creates an offset in the direction of the preferred orientation relative to the direction of the borehole. There are many ways in which this can be achieved, including approaches with displacement without rotation (relative to the wellbore) and with eccentric actuators that exert force on the drill bit in the required direction of guidance. Also, guidance is obtained by creating non-collinearity between the drill bit and at least two other tangent points. In its idealized form, the side bit is required from the drill bit to create a curved borehole. Examples of systems for repelling the entire arrangement from the axis of the well and the principles of their operation are described in US patent No. 5265682; 5,553,678; 5,803,185; 6,089,332; 5,695,015; 5,685,379; 5,706,905; 5,553,679; 5,673,763; 5,520,255; 5,603,385; 5,582,259; 5,778,992; 5971085, all incorporated herein by reference.

Known forms of RUS are equipped with an opposite rotation mechanism rotating in a direction opposite to the direction of rotation of the drill string. Usually the opposite rotation occurs at the same speed as the rotation of the drill string so that the section of the opposite rotation maintains one angular position relative to the surface of the wellbore. Since the section of the opposite rotation does not rotate relative to the wellbore, specialists in the art often call it geostationary. In this description, no distinction is made between the terms opposite rotation and geostationary.

In the system of repelling the entire arrangement from the axis of the well, a centralizer with a gesture is usually used

- 2 019369 with both blades of both external and internal opposite rotation. The centralizer of the opposite rotation with rigid blades remains at a fixed angle (or geostationary) relative to the borehole wall. When the wellbore is subject to deviation, the actuator presses the deflecting support against the wall of the wellbore in the opposite direction from the desired deviation. As a result, the drill bit is pushed in the required direction.

The force created by the actuators / deflecting bearings balances the bending force of the bottom of the drill string, and the reaction force acts through the actuators / deflecting bearings on the opposite side of the bottom of the drill string, and the reaction force acts on the cutting elements of the drill bit, thus guiding wellbore. In some situations, the force from the deflecting supports / actuators may be large enough to create formation erosion if the system is used.

For example, in the 8CMGLegdeg Po / Us6 system, there are three deflecting supports located around the bottom section of the drill string to be synchronously deployed from the bottom of the drill string to push the bit in a certain direction while guiding the well being drilled. In the system, the deflecting supports are installed close, within 1-4 feet (0.3-1.2 m) behind the bit and are driven / driven by a mud stream taken from the circulation fluid. In other systems, you can use the axial load on the bit created by the drilling system, or a wedge, or the like. to orient the drilling system in the wellbore.

Although the system and methods of applying force against the borehole wall and using reactive forces pushing the drill bit in a certain direction or biasing the drill bit in the required direction can be used with drilling systems that include a rotary drilling system, systems and methods can to have flaws. For example, such systems and methods may require great effort to be applied to the borehole wall to bend the drill string and / or orient the drill bit in the borehole; such efforts may be of the order of 5 kN or more, which may require the creation of large / complex downhole hydraulic motors or the like. In addition, many systems and methods can use the cyclic abutment of the deflecting supports / actuators outward to the borehole walls when the bottom of the drill string is rotated to create reactive forces pushing the drill bit, which may require difficult / expensive / expensive synchronization systems, complex control systems and / or the like.

SUMMARY OF THE INVENTION

The present invention generally relates to a method and a control system for a drilling system configured for drilling or coring through a geological formation. More specifically, but not by way of limitation, embodiments of the present invention utilize random variations in drilling parameters, i.e. the transient movement of the drilling system in the wellbore during the drilling process and the interaction between the drilling system and the surface of the wellbore resulting from the transient movement of the drilling system to control the drilling system and / or the drilling process.

Accordingly, embodiments of the present invention provide control of cyclic interactions between a drilling system and a borehole surface during a drilling process and use of cyclic interaction control between a drilling system and a borehole surface to control the operation / functioning of a drilling system. In some embodiments, cyclic interactions between one or more sections of the drilling system and the surface of the wellbore can be controlled to provide guidance to the drilling system for directional drilling of the wellbore. In other embodiments, cyclic interactions between one or more sections of the drilling system and the surface of the wellbore can be controlled to provide control of the operation of the drilling system, such as controlling the operation of the drill bit during the drilling process.

Accordingly, in one embodiment of the present invention, there is provided a guidance method for a drilling system configured to drill a wellbore in a geological formation, comprising: controlling dynamic interactions between sections of the drilling system and the surface of said wellbore;

the use of controlled dynamic interactions between sections of the drilling system and the surface of said wellbore to control the drilling system.

In some aspects, the step of controlling dynamic interactions between sections of the drilling system and the surface of said wellbore comprises creating non-uniform dynamic interactions between sections of the drilling system and the wall of the wellbore. Moreover, the step of regulating dynamic interactions between the drilling system section and the surface of said wellbore may comprise creating a change in the interactions between the drilling system section and the circumferential surface around the drilling system section.

In rotary drilling systems, a section of the drilling system that provides dynamic control

- 3 019369 interactions, can be installed geostationary in the wellbore during operation of the drilling system. In some embodiments, dynamic interactions can be controlled to provide guidance to the drilling system. In other embodiments, dynamic interactions can be controlled to provide control of the drill bit.

In some embodiments of the present invention, adjusting the dynamic interaction between at least the section of the drilling system and the surface of said wellbore may comprise connecting the contact element to the drilling system and using the contact element to control the dynamic interaction. In a rotary drilling system, the contact element can be held geostationary in the wellbore during operation of the drilling system.

In some aspects of the present invention, the contact element is configured to create a non-uniform dynamic interaction with the surface. In such aspects, the contact element may be asymmetric, may be non-uniformly flexible, may include a cylinder eccentrically connected to the bottom of the drill string, may comprise an element with non-uniform weight distribution and / or the like.

In some embodiments, the contact element may comprise a telescopic element that can be pulled outward from the drilling system to and / or in contact with the surface. A retractable member can be used to apply force to the surface to control dynamic interactions. The force applied to the surface may be less than 1 kN.

In some aspects, the contact element may be coupled to the drilling system such that a contact element is created within the cutting contour of the drill bit. In other aspects, the contact member may be coupled to the drilling system such that at least a portion of the contact member extends beyond the cutting contour of the drill bit.

In some embodiments of the present invention, a drive device may be used to modify / control the dynamic movement of the drilling system during the drilling procedure. In some embodiments of the present invention, a processor may be used to control a dynamic interaction control system between the drilling system and the surface. Controlling a system for managing dynamic interactions between a drilling system and a borehole surface may include installing the system on the drilling system and / or moving the system on the drilling system. In some aspects, the control processor may receive data from sensors related to the drilling process, the operation of the drilling system and / or components of the drilling system, the positions of the drilling system and / or components of the drilling system, the location of the project object of the wellbore in the geological formation, conditions in the wellbore, properties of the geological formation and / or part of the geological formation during drilling, properties of the dynamic movement of the drilling system and / or various sections of the drilling system and / or the like.

In some embodiments of the present invention, the control of dynamic interactions between the drilling system and the surface of the borehole can provide a change in the wall profile of the borehole. In some aspects, a device such as an asymmetric drill bit, an auxiliary drill bit, a retractable member extending from the drilling system to the wall, an electric pulse drill bit, an inkjet device and / or the like can be controlled with a non-uniform profile of the barrel wall to provide dynamic control interactions between the drilling system and the wall.

In embodiments of the present invention, a system or method for controlling dynamic interactions between a drilling system and a surface of a drilled wellbore can be controlled in real time, providing real-time control of the drilling system. The configuration of the controller of dynamic interactions can be determined theoretically, experimentally, by modeling dynamic interactions, from experience with previous drilling processes and / or the like. In some aspects, the dynamic interaction controller may comprise a contact element mounted less than 10 feet (3 m) above the drill bit, may comprise a contact element, with an outer surface indented less than millimeters inward of the drilling bit contour, may comprise a contact element an element with an external surface located protruding to a distance of the order of millimeters per contour of drilling a drill bit.

Brief Description of the Drawings

In the figures, the same components and / or features may have the same reference position. Additionally, various components of the same type can be distinguished by the position of the dash links and the second position, which distinguish them among similar components. If only the first position is used in the description, the description is applicable to one of the similar components having the same first position regardless of the second position of the link.

The invention will become more apparent from the following description of non-limiting and illustrative embodiments given with reference to the accompanying drawings.

In FIG. 1 schematically shows a wellbore drilling system.

- 4 019369

In FIG. 2A is a schematic illustration of a guidance system for a drilling system for drilling a wellbore according to an embodiment of the present invention.

In FIG. 2B is a sectional view of the compliant system used to guide the borehole drilling system of FIG. 2A, according to an embodiment of the present invention.

In FIG. 3A-C schematically illustrate a cam control system for guiding a drilling system according to an embodiment of the present invention.

In FIG. 4A-C schematically illustrate active calibrating deflecting support systems for guiding a drilling system configured to drill a wellbore according to an embodiment of the present invention.

In FIG. 5 schematically shows a vibration application system for guiding a drilling system for directional drilling of a wellbore according to an embodiment of the present invention.

In FIG. 6A and 6B show systems for selectively characterizing the surface of a borehole to guide a drilling assembly for directional drilling of a borehole according to an embodiment of the present invention.

In FIG. 7A is a flowchart of a guidance method of a drilling system for directional drilling of a wellbore according to an embodiment of the present invention.

In FIG. 7B is a flowchart of a method for controlling a drilling system for drilling a borehole in a geological formation according to an embodiment of the present invention.

DETAILED DESCRIPTION OF THE INVENTION

The following description provides only exemplary embodiments of the invention and is not intended to limit its scope, applicability, or configuration. Instead, the following description of exemplary embodiments is intended to enable one skilled in the art to implement one or more exemplary embodiments. Various changes in the functions and arrangement of the description elements can be made without departing from the essence and scope of the invention set forth in the attached claims.

Specific details are given in the following description to provide an in-depth understanding of the embodiments.

However, one skilled in the art should understand that the embodiments can be practiced practically without these specific details. For example, systems, structures, and other components may be shown as components in block diagram form so as not to obscure embodiments with unnecessary details. In other cases, well-known processes, techniques, and other methods can be shown without unnecessary details in order to avoid obscuring the embodiments.

We also note that individual embodiments may be described as a process shown in a flowchart, a flowchart, a flow chart, or a flowchart. Although a flowchart may describe operations as a sequential process, many operations can be performed in parallel or simultaneously. In addition, the order of operations can be changed. Additionally, any one or more operations may not occur in some embodiments. The process ends when its operations are completed, but may have additional steps not shown in the figures. The process may correspond to a method, procedure, etc.

This invention generally relates to a method and system control system for directional drilling of a wellbore through a geological formation. More specifically, but not by way of limitation, embodiments of the present invention provide the use of hitherto underestimated and unstudied random changes in drilling process parameters, or unsteady / unsteady movement of the drilling system in the wellbore during the drilling process and interactions between the drilling system and the wellbore, resulting from unsteady / unsteady movement of the drilling system to control the drilling system and / or the drilling process.

In one embodiment of the present invention, there is provided a system and method for controlling interactions between a borehole system for drilling a borehole and a surface of a borehole being drilled as a result of unsteady / unsteady movement of the borehole system during the drilling process, to provide guidance to the borehole system for directional drilling of the borehole through the geological layer. In some aspects of the present invention, the drilling system can be controlled to ensure that the wellbore reaches the project site or is drilled through the project site. In another embodiment of the present invention, data regarding the functioning of the drilling system can be recorded and controlled between the drilling system for drilling the wellbore and the surface of the wellbore in response to measurement data for controlling the drilling system, i.e. the interaction between the drill bit and

- 5 019369 by a geological formation, etc., while drilling a wellbore.

In FIG. 1 schematically shows a wellbore drilling system. As shown in FIG. 1, the drill string 10 may include a connecting device system 12 and an assembly 17 of the bottom of the drill string and may be located in the wellbore 27. The bottom hole assembly 17 may comprise a drill bit 20, along with various other components (not shown), such as a sub-bit sub, a downhole hydraulic motor, hard-blade centralizers, heavy drill pipes, thick-walled drill pipe, impact release devices (jars), sub for various forms of thread and / or the like The bottom hole assembly 17 may create a force on the drill bit 20 to destroy the rock, this force may create an axial load on the bit or the like, and the bottom drill string assembly 17 may be configured to withstand harsh environments with high working environments temperatures, high pressures and / or corrosive chemicals. The bottom hole assembly 17 may include a downhole hydraulic motor, directional drilling and measurement equipment, measurement tools while drilling, logging tools while drilling, and / or other specialized devices.

The weighted drill pipe may be a component of the weight of the drill string, which can be used to create axial load on the bit. Thus, the weighted drill pipes may be a thick-walled, heavy, tubular component, which may have a cavity in the Central channel to create the passage of drilling fluids through the weighted drill pipe. The weighted drill pipe may be round outside for passage through a borehole 27 of a drilling well and, in some cases, may be machined by a machine tool to create spiral grooves (spiral weighted drill pipes). Weighted drill pipes contain threaded connections that are plugged in at one end and spanning at the other, so that multiple weighted drill pipes can be screwed together with other downhole tools, which together can make up the bottom 17 of the drill string.

Gravity acts on a large mass of a weighted drill pipe (s) to create the significant downward force that a drill bit 20 may require to destroy the rock and drill through the geological formation. To accurately control the amount of force applied to the drill bit 20, the driller can carefully monitor the weight of the drilling system on the hook, measured when the drill bit 20 is not in contact with the bottom surface 41 of the bottom of the wellbore 27. Then, the drill string (and drill bit) can be slowly and carefully lowered to touch the surface 41 of the bottom of the bottom of the wellbore 27. After this point, as the driller continues to lower the drill string, more weight falls on the drill bit 20 and, accordingly, less weight falls on the hook on the surface. If a surface measurement shows a weight of 20,000 pounds (9080 kg) less than a weight with a drill bit 20 that does not touch the surface 41 of the bottom of the bottom, then a force of 20,000 pounds (9080 kg) should fall on the drill bit 20 (in a vertical well). Downhole sensors can be used to more accurately measure the axial load on the bit and transmit data to the surface.

The drill bit 20 may contain one or more cutting elements 23. In operation, the drill bit 20 can be used to destroy and / or cut rock on the surface 41 of the bottom of the bottom for drilling the wellbore 27 through the geological formation 30. The drill bit 20 can be located below systems 12 of the connecting device and the drill bit 20 can be changed when the drill bit 20 becomes dull or becomes incapable of drilling through the geological formation 30. The drill bit 20 and cutting elements 23 can be made with different configurations for creating various interactions with the geological formation and creating various cutting configurations.

A conventional drill bit 20 works by drilling a borehole slightly larger than the maximum outer diameter of the drill bit 20, where the diameter / gauge of the wellbore 27 is obtained by the radius of action of the cutting elements of the drill bit 20 and the interaction of the cutting elements with the rock being drilled. This drilling of the wellbore 27 with the drill bit 20 is obtained by combining the cutting action of the rotation of the drill bit 20 and the axial load on the bit created by the weight on the drill bit obtained from the mass of the drill string. In general, a drilling system may include a deflecting support (s) that may extend outward into the caliber of a wellbore 27. The calibrating deflecting bearings may comprise deflecting supports located on the bottom assembly of the drill string 17 or deflecting supports at the ends of some cutting elements of the drill bit 20 and / or the like. Gauge deflection bearings can be used to stabilize the drill bit 20 in the wellbore 27.

The connecting device system 12 may comprise pipe (s), such as a drill pipe, casing or the like, a flexible tubing and / or the like. Pipe, flexible tubing, or the like. connecting device systems 12 can be used to connect equipment 33 on the surface to the bottom assembly 17 and drill bit 20. A pipe, flexible tubing, or the like. can serve for pumping drilling mud

- 6 019369 to the drill bit 20 and lifting, lowering and / or rotation of the assembly 17 of the bottom of the drill string and / or drill bit 20.

In some systems, surface equipment 33 may include a top drive, a rotor or the like, a pipe, a flexible tubing or the like, which can transmit rotation to the drill bit 20. In some systems, the top drive may have composed of one or more motors, electric, hydraulic and / or the like, which can be connected by appropriate gear mechanisms to a short section of pipe called a locking spindle. The locking spindle can, in turn, be screwed into a safety sub or drill string, casing or flexible tubing. The top drive can be suspended on a hook to move freely up and down the tower. Pipe, flexible tubing, or the like. can be fastened with top drive, rotor or the like. to transmit rotation down in the wellbore 27 to the drill bit 20.

In some drilling systems, downhole motors (not shown) may be located downhole in the wellbore 27. Downhole motors may include electric motors, hydraulic motors and / or the like. Hydraulic motors can be driven by drilling fluids or other fluids pumped in the wellbore 27 and / or circulated in the drill string. Downhole motors can be used to drive / rotate the drill bit 20 on the surface 41 of the bottom of the bottom. The use of downhole motors can provide for the drilling of a wellbore 27 by rotating the drill bit 20 without rotating the connecting device system 12, which can be held stationary during the drilling process.

The rotation of the drill bit 20 in the wellbore 27, both produced by the rotation of the drill pipe and the downhole motor, can create the destruction and / or cutting of the rock of the surface 41 of the bottom of the bottom for drilling a new section of the wellbore 27 in the geological formation 30. Drilling fluids can be injected into the wellbore 27 wells through a system 12 of a connecting device or the like to actuate the drill bit 20, rotate the drill bit 20 or the like, to drill a wellbore 27, to remove cuttings from the surface 41 of the bottom of the bottom and / or the like

In some drilling systems, hammer bits can be used to grind the rock vertically in a manner similar to that used with pneumatic jack hammers at construction sites. In other drilling systems, downhole hydraulic motors can be used to operate the drill bit 20 or an associated drill bit or to drive the drill bit 20 in addition to the drive created by the top drive, rotor, drilling fluid and / or the like. Additionally, fluid jets, electrical impulses, and / or the like. can also be used for drilling a wellbore 27 or in combination with a drill bit 17 for drilling a wellbore 27.

In some drilling processes, a curved pipe (not shown), known as a curved sub, or a tilt / swivel mechanism can be positioned between the drill bit 20 and the downhole motor. Crooked sub or the like can be installed in the wellbore to ensure that the drill bit 20 meets the surface plane 41 of the bottom of the bottom of the bottom in a manner that enables the wellbore 27 to be drilled in a specific direction, at a specific angle, along a path and / or the like. The position of the curve of the sub can be adjusted in the wellbore without the need to remove the system 12 of the connecting device and / or layout 17 of the bottom of the drill string from the wellbore 27. At the same time, directional drilling with a curved sub or the like. can be difficult, since the efforts in the wellbore during the drilling process can impede the maneuver and / or efficient use of the sub curve to guide the drilling system.

During a drilling operation, forces that can act on the drill bit 20 may include gravity, the torque developed by the drill bit 20, the end load applied to the drill bit 20, bending moment from the drilling system including the connecting system 12 devices and / or the like These efforts, together with the type of the drilling formation and the inclination of the drill bit 20 to the plane of the surface 41 of the bottom of the bottom of the wellbore 27, can create a complex interactive system of applied and reactive forces. They turn to various systems for providing directional drilling by controlling / applying significant forces to bend / shape / guide / push the drilling system and / or to use these significant forces and / or to create significant reactive forces on the drilling system from abutting outwards formation 30 for orienting the drilling system in the wellbore and / or relative to the bottom of the bottom of the wellbore 27 and / or for repelling the drill bit 20 to guide the drilling system for inclined The direction of drilling 27 wells trunk.

At the same time, systems using the forces arising during the drilling process, for example, the end load for guiding the drilling system, can be complex and may not provide accurate guidance of the drilling system. Moreover, systems that guide the drilling system by moving / orienting the drilling system in the wellbore and / or pushing the drill bit 20 away may require creating large forces at the bottom of the well in excess of 1 kN and / or extending elements from the drill string over a considerable distance out of reach of the cut

- 7 019369 drilling bit - i.e. far beyond the contour of the drill bit, where the contour can define the outer cutting edge of the drill bit 20, creating reactive forces used to move / orient the drilling system and / or repel the drill bit 20. To repel or move the drilling system in the borehole when the drilling system rotates may also require synchronization of the application of the stop actuators to the wall of the barrel 27 of the well. Such energy generation, large exits beyond the cutting contour of the drill bit 20 and / or synchronization of the stop may require large and / or expensive engines and / or operation and management of complex systems and may complicate and / or increase the cost of drilling equipment and the drilling process.

When drilling in a straight line with a conventional drilling system, without applying lateral force 15 or the like, the applicants determined that the drill bit 20 could substantially vibrate in the wellbore 27, the vibrations comprising cyclic movement of the drill bit 20 in directions different from the direction of drilling. The term vibration / motion oscillation is used herein to describe cyclic / constant movements of the drilling system during drilling, which may have a direction in the wellbore that is different from the direction of drilling, and may be essentially random.

These vibrations / vibrations of the drilling system can be limited by the action of cutting elements dynamically acting on the surface of the wellbore and expanding it, and by calibrating deflecting supports or the like, striking the wall of the wellbore 27. As a result of the tests, it was found that drilling systems containing drill bits without calibrating deflecting supports produce a wellbore with a diameter significantly exceeding the diameter for equivalent drilling systems containing drill bits and calibrating deflecting supports. By analyzing the results of these tests, it was determined that, during the operation of the drilling system, the assembly of the bottom of the drill string 17 cyclically undergoes movement that includes moving away from the central axis of the assembly of the bottom 17 of the drill string and / or drill bit 20, i.e. in the radial direction to the wall 40 of the wellbore 27, during the drilling process. An analysis of various drilling operations found that calibrating deflecting supports limit this radial movement of the assembly 17 of the bottom of the drill string and / or drill bit 20 with the creation of a smaller borehole. Calibrating deflection supports of conventional drilling systems were deployed to minimize / eliminate vibrational movement of the drilling system to create a reduced / standard borehole.

From experimental research and analysis of drilling systems, Applicants have found that when drill bit 20 drills a geological formation 30, the cutting elements 23 can interact non-uniformly with the geological formation, for example, they can create small gravel from the geological formation 30, and, as a result, an unsteady movement that is movement in a direction different from the longitudinal / translational direction of the bottom hole assembly 17 and / or the drill bit 20 may be created in the bottom hole assembly 17 us and / or the drill bit 20. In addition, the applicants analyzed the operation of the drilling system and found that in addition to unsteady / unsteady movement during the operation of the drilling system, the application of force through the system 12 of the connecting device and drill bit 20 to the geological formation 30 at the bottom of the trunk 27 wells, work / rotation of the drill bit 20, the interaction of the drill bit 20 with the geological formation 30 at the bottom of the barrel 27 of the well (while the drill bit 20 can slip, wedge, stray from the axis of drilling and / or the like), rotation of the connecting device system 12, operation of the top drive, operation of the rotor, operation of downhole hydraulic motors, operation of drilling auxiliary systems, such as fluid jets or electrical impulse systems, well bore 20 (which may have an irregular shape) and / or the like, can create a movement in the arrangement 17 of the bottom of the drill string and / or drill bit 20, and this movement can be a cyclic, arbitrary, unsteady movement, while at least the component of the movement is not directed along the axis of the assembly 17 of the bottom of the drill string and / or drill bit 20 and is directed, instead, radially outward from the axis of the type longitudinal in the center of the assembly 17 of the bottom of the drill string and / or drill bit 20. Therefore, during operations of directional drilling, the kinetics of the assembly of the bottom 17 the drill string may contain both a longitudinal movement 37 in the direction of drilling, and non-stationary, radial movements 36A and 36B, while non-stationary radial movements 36A and 36B may contain any movement of the layout 17 of the bottom of the drill string, for example Applicants' from the central axis 39 of the barrel 27 drilled wells and / or central axis 17 linking the BHA and / or drill bit 20.

In general, it is determined that the radial movement of the assembly 17 of the bottom of the drill string during the drilling process can be arbitrary, naturally unsteady. Therefore, the assembly 17 of the bottom of the drill string can undergo cyclic arbitrary radial / transient motion during the directional drilling process. For the purposes of this description, the cyclic radial / transient movement of the assembly 17 of the bottom of the drill string in the wellbore 27 during the drilling process may be referred to as dynamic motion, radial movement

- 8 019369 by a motion, an unsteady motion, a radial-dynamic motion, a radially unsteady motion, a dynamic or unsteady motion of the assembly 17 of the bottom of the drill string and / or drill string, a cyclic radial motion, a cyclic dynamic motion, a cyclic unsteady motion, vibration and, or the like

The dynamic and / or unsteady movement of the bottom of the drill string assembly 17 while drilling the borehole 27 may cause / result in the cyclical contact of the bottom assembly of the drill string 17 with the surface of the borehole 27 and / or impact on it during the drilling process. The surface of the wellbore 27 comprises a wall surface 40 and a bottom surface 41 of the bottom of the wellbore 27, i.e. the surface of the geological formation 30, forming the wellbore 27. As discussed above, the dynamic and / or transient movement of the bottom of the drill string assembly 17 can be naturally arbitrary and therefore can cause / result in arbitrary intermittent / cyclic contact and / or impact interaction between the bottom assembly of the drill string 17 and the bore surface during drilling.

Intermittent / cyclic contact and / or impact interaction between the drill string 10 and the surface of the bore during the drilling process resulting from the dynamic and / or unsteady movement of the bottom assembly of the drill string 17 may occur between one or more sections / components of the drill string 10 and the surface the trunk. For example, the sections / components may be a drill string section 10 near the drill bit 20, a bottom hole assembly 17, a drill string assembly component 17, such as, for example, a weighted drill pipe, calibrating deflectors, rigid blade centralizers, an engine block, section of the system 12 of the connecting device and / or the like For the purposes of this description of the interaction between the bottom of the drill string assembly 17 and the borehole surface, caused / resulting from dynamic and / or unsteady movement of the bottom assembly of the drill string 17 may be referred to as dynamic interactions, transient interactions, radial motion interactions, vibrational interactions and / or t .P.

In FIG. 2A is a schematic illustration of a guidance system for a drilling system for drilling a wellbore according to an embodiment of the present invention. In FIG. 2A, a drilling system for drilling a wellbore may comprise an assembly 17 of the bottom of the drill string, which, in turn, may comprise a drill bit 20. The drilling system may provide for drilling a wellbore 50 with a wall 53 and a bottom 54 of the drilling.

During the drilling process, the drill bit 20 may be in contact with the face of the drilling 54 and destroy / displace the rock on the face of the drilling 54. In an embodiment of the present invention, the sleeve assembly 55 may be coupled to the bottom hole assembly 17 of the malleable member 57. The sleeve assembly 55 may be a pipe, cylinder, structure, or the like. The coupling arrangement 55 may have an outer surface 55A.

In some aspects, where the coupling assembly 55 comprises a pipe, cylinder and / or the like, the outer surface 55A may include the outer surface of the pipe / cylinder and / or any deflecting supports, protrusions and / or the like connected to the outer surface pipe / cylinder. The coupling assembly 55 may have sections with a rough surface, coatings, protrusions on the outer surface 55A to create enhanced frictional contact between the outer surface 55A of the coupling assembly 55 and the barrel wall 53. The coupling arrangement 55 may comprise a plurality of deflecting supports configured to contact the barrel wall 53.

In some aspects, sleeve assembly 55 may include a system of calibrated deflection supports. In aspects where the coupling arrangement 55 may comprise a number of elements, such as deflecting supports or the like, the outer surface 55A may be formed by the outer surfaces of each of the elements (deflecting supports) of the coupling assembly 55. In an embodiment of the invention, the coupling assembly 55 may be configured with the layout 17 of the bottom of the drill string with the ability to create adhesion, contact, interaction and / or the like the outer surface 55A with the wall 53 of the barrel and / or the bottom 54 of the drilling during the drilling process as a result of the dynamic movement of the assembly 17 of the bottom of the drill string. The design / profile / flexibility of the outer surface 55A and / or the location of the outer surface 55A relative to the cutting contour of the drill bit 20 may provide for the regulation of the interaction between the calibrating cutting elements 24 and the wall 53 of the barrel and other cutting elements of the drill bit 20 and the bottom 54 of the drilling.

The malleable member 57 may comprise a structure that allows lateral movement of the coupling assembly 55 relative to the drill bit 20, where the lateral movement is at least partially directed toward the central axis 61 of the assembly 17 of the bottom of the drill string. In some aspects, sleeve assembly 55 may itself be laterally compliant and may couple to bottom hole assembly 17 and / or may be a bottom section assembly 17 without the use of malleable member 57.

In one embodiment of the present invention, malleable member 57 may not

- 9 019369 is uniformly pliable around the circumference. In such an embodiment, one or more sections of malleable members 57 located around the perimeter of malleable member 57 may be more laterally compliant than other sections of malleable member 57.

As stated above, during a directional drilling process, the bottom of the drill string assembly 17 or one or more sections of the bottom of the drill string assembly may experience dynamic interaction with the bore wall 53 and / or the borehole bottom 54. In an embodiment of the present invention, sleeve assembly 55 may be configured to provide dynamic movement of the bottom of the drill string assembly 17 to dynamically interact between sleeve sleeve 55 and bore wall 53 and / or downhole 54 of the borehole during the drilling process. In various aspects of the present invention, differing outer circles, such as sleeve assemblies 55 and bottom drill string assemblies 17 and / or drill bit 20, can provide various dynamic interactions between sleeve coupling 55 and bore wall 53 and / or drilling face 54. Modeling, theoretical analysis, experimentation and / or the like. can be used to select the relative differences of the external circles between the coupling assembly 55 and the assembly 17 of the bottom of the drill string and / or drill bit 20 for a particular drilling process to produce the desired / required dynamic interaction.

In an embodiment of the present invention, in which the lateral compliance of the compliant member varies around the circumference of the compliant member 57, the dynamic interaction between the sleeve assembly 55 and the barrel wall 53 and / or the bottom hole 54 may not be uniform in circumference around the sleeve assembly 55. By way of example only , malleable element 57 may include a reduced compliance area 59B and an increased compliance area 59A. In some aspects, dynamic interactions between the sleeve assembly 55 and the bore wall 53 and / or the downhole 54 of the drill over a section of the compliant member 57 with increased lateral compliance, i.e. the area of increased compliance 59A, can be damped in comparison with the dynamic interactions between the sleeve assembly 55 and the wall 53 of the barrel and / or the bottom 54 of the drilling over the section of the compliant element 57, with reduced lateral compliance, i.e. area 59B of reduced compliance.

In some embodiments of the present invention, the coupling assembly 55 may be configured to couple the coupling assembly 55 to the bottom of the well to position the coupling assembly 55 completely in the cutting circuit 21 of the drill bit 20, the cutting circuit 21 containing a profile of cutting elements from edge to edge of the drill bit 20 In other embodiments of the present invention, the coupling arrangement 55, the coupling assembly section 55, the outer surface 55A and / or the outer surface section 55A may extend beyond ur 21 cutting. By way of example only, the sleeve assembly 55 may be coupled to the bottom hole assembly 17 so that the outer surface 55A is located inside the cutting path 21 with an indent of the order of one to tens of millimeters from it. In other aspects, and again by way of example only, the sleeve assembly 55 may be coupled to the bottom hole assembly 17 such that at least a portion of the outer surface 55A is released within tens or more millimeters per cutting path 21.

In FIG. 2B shows a cross-section through a compliant system for use in the guidance system of a drilling system for drilling a wellbore of FIG. 2A according to an embodiment of the present invention. Compliant member 57 shown in cross section in FIG. 2B contains an area of increased compliance 59A and a reduced compliance area 59B. In some aspects, there may be a single area in malleable member 57 having increased or decreased compliance with respect to the remaining area and / or other areas of malleable member 57. In other aspects, malleable member 57 may include any configuration of malleable sections creating non-uniform malleability around malleable member 57.

In FIG. 2B, malleable member 57 is shown as a solid cylindrical structure, however, in various aspects of the present invention, malleable member 57 may include other types of structures, such as a plurality of malleable members, arranged around the bottom of the drill string assembly 17 and configured to couple the coupling assembly 55 to the assembly 17 the bottom of the drill string, the layout of the supporting elements with the possibility of connecting the coupling arrangement 55 with the layout 17 of the bottom of the drill string, creating lateral movement of the coupling layout 55 and / or the like In other aspects of the present invention, sleeve assembly 55 may itself be an integral compliance structure, wherein integral compliance may be selected to be non-uniform around sleeve assembly 55, and sleeve assembly 55 may be coupled to bottom hole assembly 17 or may be a core section 17 assembly section without malleable member 57. In further aspects, the sleeve assembly 55 may comprise a plurality of malleable members, such as deflecting supports or the like, with a plurality of atlivyh elements connected to the arrangement 17, the bottom hole assembly and at least one of the flexible elements with pliability, differs from other flexible elements.

- 10 019369

In an embodiment of the present invention, the area of increased compliance 59A may be located on the compliant member 57 so that it is diametrically opposed to the area of reduced compliance 59B. In such an embodiment, malleable member 57 may prevent the sleeve assembly 55 from moving inwardly at the reduced compliance area 59B (upward, as shown in FIG. 2A), but may allow the coupling assembly 55 to move inwardly at the increased flexibility area 59A (downward, as shown in FIG. . 2A). As a result, the drill bit 20, when undergoing dynamic movement during the drilling process, can interact with the wall 53 and / or the bottom face 54 of the drilling and can tend to move, orient, or preferably destroy / remove the rock in the direction of the area of increased compliance 59A (up, as shown in Fig. 2A) and / or to it. In such an embodiment, as a result of the selected non-uniform flexibility of the compliant member 57, during the drilling process, as a result of the dynamic movement of the bottom assembly 17 and the drill bit 20, the compliant member 57 may provide guidance to the drilling system and may provide directional drilling of the wellbore 50 . Inhomogeneous interactions of the drilling system and the surface of the wellbore 27 can also be used to control interactions and as a result of the functioning of the drill bit 20 in the geological formation during the drilling process.

In embodiments of the present invention, any non-uniform circumferential compliance of the coupling assembly 55 or compliant member 57 may provide guidance / control to the drilling system. The value of the difference in flexibility in the coupling arrangement 55 and / or the flexible element 57 and / or the profile of the inhomogeneous compliance of the coupling configuration 55 and / or the flexible element 57 can be selected to create the necessary response for guidance and / or control of the drill bit 20. Response for guidance and / or the response of the drill bit of the drilling system to the difference in compliance and / or the compliance profile around the circumference can be determined theoretically, modeled, derived from experimental studies, calculated by analysis previous drilling processes and / or the like.

In embodiments of the present invention configured for use with a drilling system that does not include the use of a rotating drill bit, or where the body of the drilling system, i.e. the bottom hole assembly is non-rotatable; sleeve assembly 55 and / or malleable member 57 may be coupled to the drilling system or housing. In such an embodiment, the drilling system can be positioned in the wellbore with an area of increased compliance 59A located with a specific orientation to the drill bit 20 to allow for drilling of the wellbore 50 in the direction of the area of increased compliance 59A. To change the direction of drilling through the drilling system, the position of the area of increased compliance 59A can be changed.

In some embodiments, a positioning device 65, which may include a motor, a hydraulic actuator, and / or the like, can be used to rotate / expose the coupling assembly 55 and / or malleable member 57 to allow the wellbore 50 to be drilled by the drilling system in the desired direction . The positioning device 65 may be coupled to the processor 70. The processor 70 may control the positioning device 65 to provide the necessary directional drilling. The processor 70 can determine the correct position of the coupling assembly 55 and / or compliant member 57 in the wellbore 50 for the desired direction of drilling with operator intervention, the endpoint of the target of the wellbore, the desired drilling path, the required response of the drill bit, the necessary interaction of the drill bit with the geological formation , seismic data, input from sensors (not shown) that can provide data regarding the geological formation, conditions in the wellbore 50, data from the storm (such as axial load on the bit, drilling speed and / or the like), vibration data of the drilling system, dynamic interaction data and / or the like. data regarding the location / orientation of the drill bit in the geological formation, data regarding the trajectory / direction of the wellbore and / or the like.

The processor 70 may be coupled to a display (not shown) to display the orientation / direction / location of the wellbore 50, the drilling system, the drill bit 20, the coupling assembly 55, the malleable member 57, the drilling speed, the drilling path, and / or the like. The display can be located far from the drilling site, data can be transmitted to it through a connection such as an Internet connection, a web connection, a telecommunication connection and / or the like, and can provide remote control of the drilling process. The data of the processor 70 can be stored in a storage device and / or transmitted to other processors and / or systems associated with the drilling process.

In another embodiment of the present invention, the drill bit guidance / functional control system may be configured for use with a rotary type drilling system in which the bottom hole assembly 17 and / or the drill bit 20 may rotate during the drilling process and, therefore, the drill bit 20 and / or the bottom hole assembly 17 may rotate in the wellbore 50. In such an embodiment, the coupling arrangement

- 11 019369 and / or malleable element 57 can be made so that the movement of the coupling assembly 55 and / or malleable element 57 is independent or at least partially independent of the rotation of the drill bit 20 and / or the bottom hole assembly 17. In this case, the coupling arrangement 55 can be kept geostationary in the wellbore 50 during the drilling process.

In some aspects, clutch assembly 55 and / or compliant member 57 may be a passive system comprising one or more cylinders located around a drilling system. One or more cylinders may, in some cases, be positioned around the assembly 17 of the bottom of the drill string of the drilling system. One or more cylinders can be configured to rotate independently of the drilling system. In such aspects, one or more cylinders can be configured to provide fixation, preventing friction between one or more cylinders and the formation of rotation of one or more cylinders relative to the rotating drilling system. In some aspects of the present invention, one or more cylinders can be locked onto the bottom of the drill string assembly when there is no axial load on the bit, and therefore there is no drilling of the wellbore, and orientated and removed from the stop to the bottom drill string configurations when axial load is applied to bit and start drilling; while friction between one or more cylinders and the surface supports the orientation of one or more cylinders. In some aspects of the present invention, one or more cylinders may be coupled to a drill string assembly 17 on a bearing or the like.

In some embodiments of the present invention, it is possible to create a positioning of one or more cylinders, as in a non-rotating drilling system, using a positioning device 65 that can rotate one or more cylinders to reposition the active region of the cylinder in the wellbore 50 to change the direction of drilling and / or the operation of the drill bit 20. For example, the malleable member 57 may comprise a cylinder and may rotate around the assembly 17 of the bottom of the drill string to change location of the area of increased compliance 59A and / or area of reduced compliance 59B to change the direction of drilling of the drilling system resulting from the dynamic interaction between the coupling assembly 55 and the wall 53 of the barrel. Alternatively, active control can be used to maintain the required orientation / position of the sleeve assembly 55 and / or compliant member 57 with respect to the bottom hole assembly 17 during the drilling process. In addition, this type of device can be used in the layout of the engine to replace a curve sub. This can be advantageous from the point of view of layout flights to the wellbore due to restrictions of the tubing and completion and when they are drilled in a straight line in rotary mode.

In FIG. 3A-3C schematically illustrate a cam control system for guiding a drilling system according to an embodiment of the present invention. In FIG. 3A shows a directional drilling system with a cam control system according to an embodiment of the present invention. In FIG. 3A shows a drilling system drilling a wellbore 50 through a geological formation. The drilling system comprises an assembly 17 of the bottom of the drill string located at the end of the bore 50 of the well to be drilled / drilled. The bottom hole assembly 17 comprises a drill bit 20 in contact with the geological formation and a borehole 50 of the well.

In an embodiment of the present invention, the calibrating deflector assembly 73 may be coupled to the bottom of the drill string assembly 17 with a compliant coupler 76. The calibrating deflector assembly 73 may include a weighted drill pipe, a cylinder, non-cutting ends of one or more cutting elements of the drill bit 20 and / or etc. In FIG. 3B shows an arrangement 73 of a calibrating deflection support of the system of FIG. 3A according to one aspect of the present invention. As shown, the arrangement 73 of the calibrated deflection support may comprise a cylinder 74A with a plurality of deflection supports 74B located on the surface of the cylinder 74A. In some aspects, the plurality of deflecting supports 74B may have ductility, while in other aspects, the plurality of deflecting supports 74B may be unstable and may be metallic. In some embodiments, implementation of the present invention, the assembly 73 of the calibrating deflection support may itself be compliant, and the compliant arrangement of the calibrating deflection support may be connected to the assembly element 17 of the bottom of the drill string without a flexible coupling 76.

In one embodiment of the present invention, cam 79 may be coupled to the bottom hole assembly 17. Cam 79 may be movable on the bottom hole assembly 17. In an embodiment of the present invention, cam 79 may comprise an eccentric / asymmetric cylinder. The cam 79 may be movable to contact the calibrating deflection support assembly 73. The arrangement 73 of the calibrated deflection support can be configured to contact the wall 53 and / or the bottom face 54 of the drilling during the drilling process of the wellbore 50. The calibrating deflection support assembly 73 may be directly connected to the bottom of the drill string assembly 17, coupled to the bottom of the drill string assembly 17 by means of a sleeve 76 or the like. Coupling 76 may

- 12 019369 to hold a pliable / resilient type of material that can move the assembly 73 of the calibrated deflection support relative to the assembly 17 of the bottom of the drill string.

Cam 79 may be actuated by controller 80. Controller 80 may include a motor, hydraulic system, and / or the like. and may allow cam 79 to move and / or to maintain cam 79 geostationary in wellbore 50 during the drilling process. In some aspects, the cam 79 may comprise a cylinder with an outer surface 81 and a recess 82 in the outer surface 81. In such aspects, during the drilling process, the controller 80 may move the cam 79 to an active position in which the outer surface 81 may be near the calibrating deflector assembly 73 support or in contact with it. In some embodiments of the present invention, the controller 80 may be absent and the cam 79 may, for example, be set to the active position before placing the bottom hole assembly 17 in the wellbore 50.

In one embodiment of the present invention, cam 79 can be used to control dynamic interactions between the calibrating deflector assembly 73 and the barrel wall 53 to create heterogeneous properties of the calibrating deflector arrangement 73 around the circumference of the calibrating deflector assembly 73. In further embodiments of the present invention, instead of using cam 79 to change properties, positioning, and / or the like. piezoelectric, hydraulic and / or other mechanical actuators may be used to create heterogeneous properties of the calibrator deflector assembly 73, which properties can be used to control dynamic interactions between the calibrator deflector assembly 73 and the barrel wall 53 and / or bottom hole 54 drilling.

In the active position, i.e. where the cam 79 is in contact with the calibrating deflector assembly 73, the cam 79 may counteract the lateral direction of the calibrating deflector assembly 73 moving, i.e. to the central axis of the assembly 17 of the bottom of the drill string and / or wellbore 50. In the active position, the recess 82 may be separated from the configuration 73 of the calibrating deflecting support by a gap 83, where the gap 83 is larger than the gap between the layout 73 of the calibrating deflecting support and the outer surface 81 in other positions around the system. In this case, part of the arrangement 73 of the calibrating deflecting support over the recess 82 may have more freedom / ability to move sideways in comparison with other sections of the arrangement 73 of the calibrating deflecting support located above the outer surface 81. Therefore, the interaction between the arrangement 73 of the calibrating deflecting support and the wall 53 of the barrel and / or the bottom face 54 of the drilling during the drilling process should not be uniform around the assembly 73 of the calibrating deflection support.

In some aspects of the present invention, cam 79 can be used to control a sharp change in direction of the assembly 73 of the calibrated deflector, or to create a sharp change in direction of the arrangement 73 of the calibrated deflector to guide the drilling system, or to eliminate a sharp change in direction in the arrangement 73 of the calibrated deflector to provide drilling in a straight line. In an embodiment, to control the operation of the drill bit 20, the cam 79 can be used to control a sharp change in the direction of the arrangement 73 of the calibrating deflection support, or to create a sharp change in the direction of the arrangement 73 of the calibrating deflection support to create some mode of operation of the drill bit 20 or to eliminate a sharp change in direction in an arrangement 73 of a calibrated deflection support to create a different mode of operation of the drill bit 20.

Cam 79 may comprise an eccentric cylinder. In operation, the cam 79 may be in contact with the calibrating deflector assembly 73 and may provide at least a section of the calibrating deflector assembly 73 outside the drill bit 20 gauge. As a result, the calibrating deflector assembly 73 out of the gauge may be non-uniform interact with the surface of the wellbore 50. The cam 79 may have a section with a stably varying outer diameter to create a steady change in caliber / diameter of at least a section of the assembly 73 of the calibrating deflection support during the drilling process.

During the drilling process, the bottom of the drill string assembly 17 may undergo dynamic movement in the wellbore 50, resulting in dynamic interactions between the bottom of the drill string assembly 17 and the surface of the wellbore 50. In an embodiment of the present invention, due to the greater flexibility of the calibrating deflector assembly arrangement 73 over the recess 82 as compared with the flexibility of the calibrating deflector assembly assembly 73 on the opposite side of the calibrating deflector assembly 73 relative to the recess, cyclic dynamic interactions between the calibrating deflector assembly 73 and the wall 53 the borehole and / or the bottom face 54 of the drilling should force the drilling system to drill in the direction 85 of drilling, while the direction e 85 of the drilling is directed in the direction of the recess 82. When in contact, the cam 79 can prevent the assembly 73 of the calibrating deflecting support from moving inward (up, as shown in the drawing), but may

- 13 019369 the ability to move the layout 73 calibrating deflecting bearings in the opposite direction (down, as shown in the drawing). As a result, the drill bit 20 must move, vibrate upward relative to the calibrating deflection support assembly 73, and thus create drilling with the drilling system in an upward direction toward recess 82 to create an upwardly directed section of the wellbore 50.

In an embodiment of the present invention, cam 79 may cause a sharp change, leaving the direction of the axis of the assembly 73 of the calibrating deflection support relative to the axis of the drill bit 20 in a geostationary plane. In some aspects, a sharp change in direction of the alignment of the gage diverting support 73 by the cam 79 may be created when the alignment of the calibrating diverting bearings 73 rotates with the drill bit 20 and / or the bottom hole assembly 17.

When using a drilling system for drilling a curved section of a wellbore, for example, a curved section with a deviation of 10 degrees / 100 feet (31 m), the actual wellbore drift to the side may be small; for example, in such a curved section, for progressive drilling of a borehole of 150 mm (6 inches), drift towards the borehole is 0.07 mm. In embodiments of the present invention, since sidetracking to create curved sections with a deviation of the order of 10 degrees / 100 feet (31 m) is small, it may be necessary to create only a small system for creating controlled, heterogeneous dynamic interactions with the surface of the wellbore during the drilling process deviation of the wellbore. In experiments with embodiments of the present invention, the control of dynamic interactions using couplings / calibrating deflection bearings with an eccentric profile around a circle relative to the central axis of the bottom assembly of the drill string and / or drill bit, including eccentric profiles extending beyond the drill bit and / or indented from the caliber of the drill bit, gave guidance in the curved sections of the wellbore with such necessary curvatures.

In some aspects of the present invention, to minimize the required power, the calibrating deflector assembly 73 can be mounted on a flexible coupling 76 with the axis of the calibrating deflector assembly 73 coinciding with the axis of the drill bit 20 and / or the cutting system, which may include drill bit 20. In an embodiment of the implementation of the present invention, guidance of the drilling system can be obtained using a cam 79 to narrow the direction of compliance of the flexible coupler 76 so that the comp The onovka 73 of the calibrating deflection support can move in one direction, but is very rigid (there is resistance to radial movement) in the opposite direction. In some aspects, in order to guide the drilling system in a straight line, the cam 79 may be in contact to provide stiffness (counteracting radial movement) while moving the alignment system 73 of the calibrating deflection support in all directions.

In an embodiment of the present invention, the calibrating deflection support assembly 73 may comprise one annular arrangement supporting the calibrating deflection supports in the same caliber with the drill bit 20. In some aspects, some out-of-gauge or indentation inward of the gauge may be acceptable. In alternative embodiments, the deflecting supports on the calibrating deflecting support assembly 73 may be mounted independently and / or independently in the annular arrangement. The arrangement 73 of the calibrating deflecting support can be mounted on a strong pliable structure and can be moved radially relative to the drill bit 20. The cam 79 can be eccentric and can be made geostationary when the drilling system is hovered and retracted, removed and / or the like during hoisting operations with a drill string, or when guidance is not necessary. By holding the cam 79 in a geostationary position, the active part of the cam 79, such as a recess 83 or the like, can be held in a geostationary position relative to the wellbore 50 to allow the wellbore 50 to be drilled in the desired direction, for example, in the direction of the geostationary recess 83. B in some aspects, cam 79 may be geostationary, and calibrated deflection bearings or the like. can be freely rotated during the drilling process.

The various methods described above can be used to connect the assembly 73 of the calibrating deflection support to the drill bit 20 and / or the assembly 17 of the bottom of the drill string.

In some aspects, the installation may be radially pliable, but may also be able to transmit torque and axial load to the bottom hole assembly 17. In one embodiment of the present invention, a flexible coupler 76, which may be a holder or the like, may comprise a thin-walled cylinder with grooves cut therein to provide radial flexibility while maintaining tangential and axial stiffness. Other embodiments may include bearing surfaces for weight transfer and / or studs and / or pivot arms that can be used to transmit torque.

Using the configuration configuration 73 calibrating deflection bearings and / or feed

- 14 019369 casting sleeve 76, which can keep the recess 82 (or cam section 79 going beyond the caliber or indented in gauge or a combination of cam 79 and the assembly 73 of the calibrating deflecting support or the radially rigid or radially pliable section of the arrangement 73 of the calibrating deflecting support) geostationary in the well bore 50, the movement of the drilling system can be controlled for directional drilling of the well bore 50. In some embodiments of the present invention, a processor 75 may be used to control the controller 80 to allow cam 79 to rotate during drilling operations, or between them, to continuously control direction during drilling. In some embodiments, the recess 82 may have a sloping profile 82A to create a varying depth of the recess 82. In such embodiments, the relative flexibility of the calibrating deflector assembly assembly 73 between the calibrating deflector assembly section 73 above the recess 82 and the calibrating deflecting assembly section 73 not above the recess 82 may vary. In this way, in some embodiments of the present invention, the sharpness of the angle (θ) 86 of the direction of drilling 85 can be controlled with its change.

In some aspects of the present invention, it is possible to create a plurality of recesses in the cam 79 to control interactions between the calibrating cutting elements 24 and the barrel wall 53. A plurality of recesses can be arranged to be installed in various positions around the circumference of the cam 79 to provide interaction between the calibrating cutting elements 24 and the barrel wall 53 to obtain, as a result, the desired guidance effect. Additionally, a plurality of cams can be used in conjunction with one or more arrangements of calibrating deflection bearings on the assembly 17 of the bottom of the drill string to create various guidance actions during the drilling process.

In FIG. 4A-4C schematically illustrate active calibrating deflecting support systems for controlling a drilling system for drilling a wellbore according to an embodiment of the present invention. In an embodiment of the present invention, the active calibrating deflection support 100 can be used to control the drilling system, which may include a drill pipe 90 connected to the bottom of the drill string assembly 95. The bottom of the drill string assembly 95 may include a drill bit 97 for drilling a borehole. The active calibrating deflecting support 100 may comprise a weighted drill pipe calibrating the deflecting support, a bottom hole assembly section, a pipe assembly, a drill bit section and / or the like, which may non-uniformly interact with the surface of the drilled wellbore.

The active calibrating deflecting support 100 may comprise a disk, a cylinder, a plurality of individual elements, for example, a series of deflecting supports located around the circumference of the bottom 95 of the drill string or drill pipe 90, which can be connected to the drilling system and can interact with the surface of the drilled borehole during drilling process. In some aspects, to provide cyclic interaction between the active calibrating deflection support 100 or the like. and the surface of the wellbore, the active calibrating deflection support 100 may be coupled to the drilling system so that it is less than 20 feet (6 m) above the drill bit 97. In other aspects, the active calibrating deflection support 100 may be coupled to the drilling system so that it is less than 10 feet (3 m) above drill bit 97.

In embodiments of the present invention, the active calibrating deflection support 100 may be moving in the wellbore. In this case, the active calibrating deflecting support 100 can be set in the wellbore using an actuator or the like. for orientation in the wellbore to produce the necessary control of the drilling system as a result of inhomogeneous interactions of the calibrating deflecting support 100, oriented in the wellbore along the wall of the wellbore. Using a processor or the like to control the installation of the active calibrating deflecting support 100 in the wellbore in the desired position, the operation and / or guidance of the drilling system can be controlled / controlled, and this control / control can, in some aspects, occur in real time.

In FIG. 4A, the active calibrating deflecting support 100 is connected to the bottom of the drill string assembly 95 to allow for interaction with the surface of the borehole in place near the drill bit 97. In a drilling system in which the drill pipe 90 has a bottom drill string assembly 95 and / or the like. rotate during drilling operations, an active calibrating deflecting support 100 can be made to hold it geostationary during drilling operations. Actuator, friction and / or the like can be used to hold the active calibrating deflecting support 100 geostationary. By way of example only, in one embodiment of the present invention, the active calibrating deflection support may be coupled to the bottom of the drill string assembly 95 above the drill bit 97 at a distance of less than 10-20 feet (36 m) from it.

In FIG. 4B shows one embodiment of an active calibrating deflection support of the system shown in FIG. 4A. In FIG. 4B according to an embodiment of the present invention

- 15 019369 the effective calibrating deflecting support 100A may comprise an asymmetric element. When connecting the asymmetric active calibrating deflecting support with the drill string so that the outer surface of the calibrating deflecting support 100A protrudes beyond the outer surface of the drill string, the outer surface of the asymmetric active calibrating deflecting support can interact with the surface of the drilled wellbore. Since the active calibrating deflecting support 100A has an asymmetric outer surface, the active calibrating deflecting support 100A may interact non-uniformly with the surface of the wellbore as a result of the dynamic movement of the drill string during the drilling process, which should depend on the asymmetric configuration of the active drilling deflecting support 100A.

By way of example only, the active calibrating deflection bearing 100A may be asymmetric in design and may be configured to connect to the bottom of the drill string as shown in FIG. 4A, in a range of a few inches (1 inch = 25 mm) to 1,020 feet (3-6 m) above the drill bit. In some embodiments, the active gage deflection support 100A may comprise a regular cylinder and may be eccentrically positioned on the bottom of the drill string to create a non-uniform interaction with the borehole surface as a result of the dynamic movement of the drill string.

In some embodiments, the active gage deflecting support 100A may comprise a geostationary pipe and may have a slight indentation in the gauge on one side. In other embodiments, the active calibrating deflecting support 100A may be indented inward of the caliber on one side and out of the caliber on the opposite side. In some aspects, the active gage deflection support 100A may comprise a plurality of geostationary pipes that are indented in / out of circumference, which may be joined around the circumference of the drill pipe 90 and / or the bottom of the drill string assembly 95. In some embodiments of the present invention, an active calibrating deflecting support 100A may be configured to couple an active calibrating deflecting support 100A to a drill string such that the active calibrating deflecting support 100A is located completely in the cutting contour of the drill bit; moreover, a cutting contour containing a profile of cutting elements from edge to edge of the drill bit. In other embodiments of the present invention, the section or all of the fully active calibrating deflection support 100A may extend beyond the cutting contour of the drill bit.

By way of example only, the active calibrating deflection support 100A may be coupled to the drill string to ensure that the outer surface of the active calibrating deflection support 100A is located within the cutting contour with an indent of the order of one millimeter-tens of millimeters from it. In other aspects, and again by way of example only, the active calibrating deflection support 100A may be coupled to the drill string to extend beyond the cutting contours of at least a portion of the outer surface of the active calibrating deflection support 100A ranging from tenths to tens of millimeters.

In an embodiment of the present invention, the active calibrating deflecting support 100A, since it is not concentric with the bottom of the drill string, is asymmetric and / or the like, may not uniformly interact with the surface of the drilled borehole as a result of radial movement of the drilling system in the borehole drilling process time. The cyclic dynamic interactions between the active calibrating deflection supports 100A shown in FIG. 4B and the surface of the wellbore during the drilling process may result in the tendency of the drilling system to drill downward in a direction 103, as shown in the figure. By keeping the active calibrating deflecting support 100A geostationary during the drilling process, the active calibrating deflecting support 100A can be used to guide the drilling system.

In an embodiment of the present invention, by indenting the active calibrating deflecting support 100A in at least one circumferential circumference around the closed loop of the active calibrating deflecting support 100A, a small gap can be created between the active calibrating deflecting support 100A and a surface that can be used to guide the drill bit 97. Accordingly, in some embodiments of the present invention, the drilling system can be guided using cont active surfaces on the layout 95 of the bottom of the drill string, which may be inside the profile cut through by the cutting elements and / or without pushing the contact surfaces for the cut profile.

In FIG. 4C shows a further embodiment of the active calibrating deflection support of the system shown in FIG. 4A. In FIG. 4C, the active calibrating deflecting support 100B may comprise a sleeve 105 connected to the extension member 107. The coupling 105 may include a cylinder, a disc, a weighted drill pipe, calibrating the deflecting support, a bottom hole assembly section 95, a drill string section, a drill pipe section and / or etc.

In an embodiment of the present invention, the extension member 107 may be an element that can be controlled to change the circumference of the sleeve 105. The extension member

- 16 019369 volume 107 may be controlled / powered by a controller 110. The controller 110 may include a motor, hydraulic system and / or the like. In an embodiment of the present invention, the controller 110 may actuate a telescopic extension 107 to extend outward from the bottom of the drill string assembly 95 to alter the dynamic interactions between the calibrating deflecting support 100B and the surface of the drilled wellbore as a result of radial / dynamic movement of the drilling system in the wellbore drilling process time.

In some embodiments of the present invention, an active calibrating deflection support 100B may be configured to position the extended active calibrating deflection support 100B completely in the cutting contour of the drill bit. In other embodiments of the present invention, the section or all of the extended / partially extended active calibrating deflection support 100B may extend beyond the cutting contour of the drill bit. By way of example only, the active calibrating deflecting support 100B can be connected to the drill string to ensure that the outer surface of the active calibrating deflecting support 100B is in an extended position within the cutting contour with an offset of about 1-10 mm from it. In other aspects, and again by way of example only, the active calibrating deflection support 100B may couple to the drill string to create at least a portion of the outer surface of the active calibrating deflection support 100B when it is extended or partially extended beyond the cutting contour by 1-10 mm from him.

In an embodiment of the present invention, the interactions between the active calibrating deflecting supports 100B and the surface can be controlled by positioning / extending the extension 107 to provide guidance to the drilling system and directional drilling of the borehole drilled by the drilling system. In some aspects, the processor 70 may receive data regarding a desired direction of drilling, data regarding a drilling process, data regarding a wellbore, data regarding conditions in a wellbore, seismic data, data regarding formations surrounding a wellbore and / or the like. p., and can control the operation of the controller 110 to provide positioning / extension of the sliding element 107 to guide the drilling system. In an embodiment of the present invention, the extension member 107 can be extended to adjust the dynamic interactions between the active calibrating deflecting support 100 and the surface of the well being drilled. This may require a simple passive extension of the extension 107 to make the active calibrating deflecting support 100 non-uniform around the central axis of the drilling system and / or in the wellbore without applying force against the borehole surface.

In some aspects, however, the extension 107 can be positioned extended to apply force to the surface of the barrel. By way of example only, in some embodiments, the extension member 107 can transmit a force of less than 1 kN to the surface of the barrel to provide both a transfer of reactive forces from the surface to the drilling system and to control dynamic interactions between the drilling system and the surface of the barrel. Controlling the operation of the extension member 107 to provide a force transfer of less than 1 kN may be preferable since such efforts may not require large power consumption / large power sources of downhole tools, may reduce the size and complexity of the controller 110 and / or the like.

In an embodiment of the present invention, the bottom of the drill string assembly 95, drill bit 97, active calibrating deflection support 100 and / or the like. can be performed with an unevenly distributed mass. The mass of the layout 95 of the bottom of the drill string, drill bit 97, active calibrating deflecting support 100 and / or the like can vary around the circumference to ensure unsteady movement and / or inhomogeneous interaction of the drilling system with the surface of the wellbore. In this case, the inhomogeneous weighting of the drilling system can provide control and / or guidance of the drilling system. By way of example only, a weighted drill pipe giving an axial load to the bit may be a cylinder with an uneven weight distribution. In some aspects, the cylindrical weighted drill pipe may rotate to change the profile of the non-uniform weight / mass distribution relative to the wellbore to create the necessary control of the drilling system and / or guidance of the drilling system.

In some embodiments, the implementation of the present invention instead of calibrating deflecting supports, heavy drill pipe and / or the like. or in combination with them, the drill string can be shaped to provide control for transient interactions with the surface of the barrel. For example, an assembly 95 of the bottom of the drill string may be given an asymmetric shape, it may have asymmetric compliance and / or the like. Additionally, according to some embodiments of the present invention, drill bit 97 may be asymmetric, have asymmetric compliance, have inhomogeneous cutting properties, and / or the like. Moreover, the drilling system can be designed to enhance the transient movement of the drilling system during the drilling process. Modeling, experimental studies and / or the like. can be used to develop drilling systems with enhanced transient motion. Cutting installation

- 17 019369 elements on the drill bit 97, the operating parameters of the cutting elements can be used to provide increased transient motion. In some embodiments of the present invention, the drilling system may include a flexible / pliable coupler, a curve sub, and / or the like. (not shown) capable of enhancing transient interactions, improving control of a drilling system with transient interactions, and / or the like.

In FIG. 5 schematically shows a rotary radial motion actuator system for guiding a directional drilling system of a borehole according to an embodiment of the present invention. In an embodiment of the present invention, the drilling system may comprise a drill string 140, which may in turn comprise a bottom 95 of the drill string, and the drilling system may be configured to drill a borehole through a geological formation.

In some embodiments, a radial motion generating device 150 may be bonded to a drill string 140. A radial motion generating device 150 may be configured to create a radial movement of the bottom hole assembly 95 in the wellbore; where the radial movement can be any movement of the layout 95 of the bottom of the drill string directed from the Central axis of the wellbore to the wall of the wellbore. The radial motion generating device 150 may include a mechanical vibrator, an acoustic vibrator and / or the like, which can create a cyclic radial movement, such as vibrations, the bottom of the drill string 95. The radial motion generating device 150 may be tuned to the physical characteristics of the drill string 140 and / or the bottom 95 of the drill string to provide enhanced radial movement.

In an embodiment of the present invention, interactions between the bottom hole assembly 95 and the borehole surface can be created, enhanced, modified and / or the like. by means of a radial motion generating device 150. Radial motion generating device 150 may provide guidance to drill string 140 by creating, applying, modifying and / or the like. interactions between the layout of the bottom of the drill string and the surface of the wellbore. By aiming the drill string 140, directional drilling of the borehole drilling the drill string 140 can be performed. The processor 155 can be used to control the radial motion device 150 to create interactions between the bottom 95 of the drill string and the bore surface to allow the drill string 140 to be guided direction.

In some embodiments of the present invention, the radial motion generating device 150 can be used in combination with other methods for generating non-uniform transient interactions between the drilling system and the surface of the drilled wellbore described herein. In such embodiments, the radial motion generating device 150 may provide amplification or damping of the transient motion of the drill string to enhance / damp the action of the transient controller and / or to control the transient controller. In this way, the transient controller can act as the controller / controller of the transient controller and can be controlled by the processor itself to provide control / guidance of the drilling system and / or to enhance the damping of inhomogeneous transient interactions between the transient controller and the surface of the wellbore.

In FIG. 6A and 6B show systems for selectively measuring the surface of a borehole for guiding a drilling assembly for directional drilling of a borehole according to an embodiment of the present invention. During drilling, drill string 160 can be used to drill a wellbore through a geological formation. The drill string 160 may comprise a bottom hole assembly 165 and a connecting device 170 that can connect the bottom drill string assembly 165 to equipment near a site on or on the surface. The layout of the bottom of the drill string may contain a drill bit 173, which may contain many teeth 174 for cutting / destruction of rock in the geological formation to create / continue drilling the borehole.

During the drilling process, the surface of the borehole being drilled may have a generally regular shape and may be formed by the outer diameter of the drill bit 173. In general, the surface is formed by a circle. The properties of various sections of the geological formation may cause irregular surface shape. In FIG. 6A according to an embodiment of the present invention, the forming device 180 can interact with the surface to change / shape the surface. The forming device 180 may comprise a waterjet system for blasting the surface, a drill bit configured to laterally drill into the surface, a cutting insert for cutting the surface, and / or the like.

In an embodiment of the present invention, the forming device 180 can be used to change the profile of the surface of the barrel to provide control interactions

- 18 019369 between the layout 165 of the bottom of the drill string and the surface of the barrel. In some aspects, the calibrating deflecting support 185 may be coupled to the bottom of the drill string assembly 165 near the drill bit 173 and may be configured to interact with the borehole surface while drilling the borehole with a drilling system. If the borehole surface is relatively homogeneous, arbitrary interactions between the calibrating deflecting support 185 and the borehole surface resulting from the radial movement of the bottom assembly of the drill string 165 may, during the drilling process, be uniform on average and may not affect direction drilling. In an embodiment of the present invention, the forming device 180 may create a contour / shape of the surface of the barrel to control interactions between the calibrating deflecting support 185 and the surface. In some aspects of the present invention, the bottom of the drill string assembly 165 may not include a calibrating deflection support 185, and interactions may occur directly between the bottom drill string 165 and the bore surface.

In an embodiment of the present invention, by adjusting the interactions between the calibrating deflecting support 185 and the bore surface, the drilling system can be guided. In some aspects, the forming device 180 may be kept geostationary during the pointing procedure to ensure that the bore surface to be treated with the forming device 180 during the drilling process is precisely selected when the drill string 140 and / or components of the drill string 140 can move / rotate in the wellbore.

The forming device 180 may comprise water-jet nozzles mounted between calibrating cutting elements and calibrating deflecting supports of the drill bit. Water jet nozzles or the like can be used to cut the geological formation in front of the calibrating deflecting support to create a gap between the borehole surface and the calibrating deflecting support, which can provide vibrational guidance of the drilling system according to an embodiment of the present invention. In other embodiments, electropulse systems can be installed in front of the calibrating deflecting supports and can be used to soften the barrel surface section to allow the calibrating deflecting support to destroy the material of this section to create a clearance to provide vibration guidance to the drilling system according to an embodiment of the present invention. In other embodiments, electropulse systems can be used to create a clearance directly.

Shown in FIG. 6B, a drill bit 173 may be configured to drill a borehole with a selectively heterogeneous surface. In some aspects, tooth 190 of drill bit 173 may be selectively engaged to create a surface contour. In other aspects, various techniques may be used to control drill bit 173 to selectively shape the surface of the barrel. By adjusting the contours, it is possible to control the surface shape with the selective placement of grooves, recesses or the like in the surface, the interaction between the borehole surface and the bottom hole assembly 165 resulting from the radial movement of the bottom hole assembly 165 while drilling the wellbore, and the direction of drilling can also be controlled as a result. In some aspects, the drill bit 173 may include a mechanical cutting element that can be deployed to advantageously cut one side of the surface of the barrel.

In FIG. 7A is a flowchart of a guidance method of a drilling system for directional drilling of a wellbore according to an embodiment of the present invention. At step 200, a drilling system can be used to drill a section of a wellbore through a geological formation. The drilling system may comprise a drill string attached to equipment on a surface or the like. The drill string may itself comprise a bottom hole assembly containing a drill bit for contact with the geological formation and for drilling a section of the wellbore through the geological formation. The bottom hole assembly may be connected to equipment on the surface by means of a drill pipe, casing, flexible tubing or the like. The drill bit may be driven by an overhead drive, rotor, motor, drilling fluid and / or the like. During the drilling process, the drill string may undergo arbitrary movement in the wellbore, said arbitrary movement may include radial vibrations causing the drill string to contact the surface of the wellbore during the drilling process. The interactions between the drill string and the surface resulting from radial vibrations can most significantly occur at the bottom of the wellbore, where interactions can occur between the layout of the bottom of the drill string and the surface of the bore.

At step 210, vibratory-type interactions between the drill string and the surface can be controlled. In some embodiments of the present invention, dynamic interaction control may occur at the bottom of the wellbore. In some embodiments of the present invention, devices may be used at the bottom of the borehole to create inhomogeneous interactions of the vibrational type of the bottom hole assembly and

- 19 019369 trunk tops. In such an embodiment, the step of regulating the interaction of the vibrational type between the drill string and the surface of the barrel may comprise damping and / or amplification at the work site around the surface circumference of the vibrational type interactions between the bottom assembly of the drill string and the surface. Damping and / or local reinforcement around the circumference of the surface can be maintained or enhanced when drilling a wellbore. In some aspects, a variety of devices can be used to create a heterogeneous interaction between the layout of the bottom of the drill string and the surface of the barrel.

In an embodiment of the present invention, the interaction element may be used in step 212 to create dynamic interaction control. The interaction element may be an independent element, such as a weighted drill pipe, an assembly of a calibrating deflection support, a cylinder or the like, which may be connected to the drill string, and in some aspects, the layout of the bottom of the drill string, may be a section of the drill string, such as bottom hole assembly section, or the like The interaction element can be performed to ensure uniform interaction between the interaction element and the surface of the drilled wellbore.

In general, a wellbore being drilled is a wellbore in a geological formation substantially with a cylindrical surface. Accordingly, in some aspects, the interaction element may comprise an element with a profile that is heterogeneous with respect to the central axis of the drill string and / or wellbore. By way of example only, the interaction element may comprise an eccentric cylinder connected to the bottom of the drill string; however, the central axis of the eccentric cylinder connected to the bottom of the drill string assembly is inconsistent with the center axis of the bottom of the drill string. In another example, the interaction element may include a number of deflecting supports located around the bottom of the drill string and configured to contact the cylindrical surface of the wellbore during the drilling process, with at least one deflecting support being able to extend outward from the bottom of the drill string. by an amount greater or less than other deflecting supports.

In other embodiments, the implementation of the interaction element may contain an element with heterogeneous compliance. By way of example only, a malleable element may comprise an element with some malleability and a section of the element with increased or decreased malleability relative to some malleability of the remaining elements and can be performed to create at least a portion of the region of increased or decreased malleability and at least part of the element with some flexibility can each come into contact with the cylindrical surface during the drilling process as a result of the dynamic movement of the bottom hole assembly bosoms. In some embodiments of the present invention, an actuator may be used to change the characteristics of the interaction element, such as to translate the interaction element from an element interacting uniformly with the surface of the wellbore to an element interacting non-uniformly with the surface of the wellbore.

In some embodiments of the present invention, the interaction element, as being an element with a non-uniform profile, non-uniform compliance and / or the like, may not be made to apply pressure to the surface of the barrel or to dynamically affect the surface of the barrel, but, in contrast to this , can be passive, in fact, and interact with the surface of the barrel due to the dynamic movement of the drill string during the drilling process. For example, the interaction element may include a retractable element that extends outward from the drill string. In some aspects, the forces can be applied by a retractable element to the surface of the barrel, but for simplicity and for economic reasons, the forces can be, in essence, only small, i.e. forces of less than 1 kN.

In some embodiments of the present invention, the interaction element may be such that it does not extend beyond the contour of the cutting elements of the drill bit and / or is located completely in the contour. In other embodiments, the interaction element may have at least a portion that may extend beyond the contour of the drill bit. In some aspects of the present invention, the interaction element may extend beyond the contour of the drill bit and / or cutting elements within a range of one to tens of millimeters, within the range beyond the contour providing guidance / control of the drilling system.

In some aspects of the present invention, where the interaction element contains one or more retractable elements, one or more retractable elements can be extended so as not to extend beyond the contour of the cutting elements of the drill bit and / or lie completely in the contour. In other aspects, one or more of the telescopic members may extend to create at least a portion of one or more telescopic members beyond the contour of the cutting members and / or drill bit. Guidance of the drilling system can be provided in some embodiments of the present invention by extending one or more retractable elements within 1-10 mm beyond the contour of the cutting elements and / or drill bit. In such embodiments, in

- 20 019369 difference from directional drilling systems using reactive forces, abutment against the borehole wall for guidance, only a small power and / or minimal downhole equipment can be used / may be necessary to actuate and / or maintain the necessary extension of the retractable elements beyond the contour of the cutting elements and / or drill bit.

In some aspects of using multiple devices, a combination of devices can be made to provide heterogeneous interactions between the drill string and the surface of the bore around the drill string and, in such configurations, connecting multiple devices to the drill string in a manner in which the effect of one device on dynamic interactions neutralizes the effect another device can be prevented. Devices that can be used to control dynamic interactions can include, but are not limited to, the following devices: calibrating deflecting supports, weighted drill pipes, a centralizer with rigid blades, and / or the like, which may be placed non-concentrically on the bottom of the drill string. ; calibrating deflecting supports, weighted drill pipes, centralizers with rigid blades and / or the like, which can be made with compressibility inhomogeneous around the circumference; devices for changing the profile / shape / contour of the surface; drill bits made for drilling a borehole with an incorrect internal surface; and / or the like

At step 220, the drilling system can be guided by controlling vibratory-type interactions between the drill string and the surface of the wellbore. In an embodiment of the present invention, devices used to control dynamic interactions between the drill string and the surface of the wellbore can be selectively installed in the wellbore to create dynamic guidance interactions of the drilling system. In drilling systems in which at least a portion of the drill string rotates during the drilling process, the devices can be held geostationary in the wellbore to provide guidance. In some embodiments of the present invention, devices used to control dynamic interactions between the drill string and the surface of the wellbore can be selectively mounted on the drill string before drilling a section of the wellbore to create the necessary guidance for the drilling system. In some aspects, devices used to control dynamic interactions between the drill string and the surface of the wellbore can be reinstalled before drilling an additional section of the wellbore. In embodiments where an actuator, such as a cam or the like, is used to change the properties of the device used to control the dynamic interactions between the drill string and the surface of the wellbore, the cam instead of the device used to control the dynamic interactions can be selectively set and / or reinstall during the drilling process.

In some embodiments of the present invention, means for controlling the position in the wellbore, orientation in the wellbore, location and / or orientation on the drill string of a device used to control dynamic interactions between the drill string and the surface of the wellbore, and / or device to turn on the device used to control dynamic interactions between the drill string and the surface of the wellbore, such as a cam or the like, can be used zovat for moving the devices used to control the dynamic interactions between the drill string and the surface of the wellbore during the drilling process.

At step 230, the guidance system is drilled to drill the wellbore in the desired direction. In an embodiment of the present invention, it is possible to determine the necessary direction of the borehole section to be drilled, and a device used to control dynamic interactions can be installed in the borehole and / or on the drill string to guide the drilling system to drill the borehole section in the required direction. In some aspects, the processor may control position, orientation, and / or the like. a device used to control dynamic interactions in the wellbore and / or on the drill string to allow drilling of a section of the wellbore to be drilled in the required direction. In some embodiments, data from sensors located on the drill string, data from sensors located in the wellbore, data from sensors located in the geological formation near the wellbore, seismic data and / or the like. can be processed by the processor to determine the orientation position of the device used to control dynamic interactions for the desired direction of drilling.

In FIG. 7B is a flowchart of a method for controlling a borehole system for drilling a borehole in a geological formation according to an embodiment of the present invention. At step 240, a drilling system comprising a drill string and a drill bit configured to drill a borehole in a geological formation may be used to drill a section of a borehole. At step 250, data regarding the operation of the drill string and / or drill bit during the drilling process can be recorded. Data may include items such as axial load on the bit, rotational speed of the drilling system, load on the hook, torque

- 21 019369 moment and / or the like. In addition, data can be collected in the wellbore, on equipment on the surface, in the formation surrounding the wellbore, and / or the like, and data related to drilling activities / processes to be performed or to be performed during drilling can be entered . For example, pressures and / or temperatures in the wellbore and formation can be determined, seismic data can be obtained in the boreholes and / or formation, the properties of the drilling fluid and / or the like can be identified.

At step 260, measurement data regarding the drilling system and / or data regarding the geological formation and / or conditions in the well being drilled and / or the like can be processed. The processing may be definitely / probabilistic in nature and may identify the current and / or potential future states of the drilling system. For example, you can identify the conditions and / or potential conditions of the drilling system, such as indicators of the inefficiency of the drill bit, jamming of the drill bit and / or the like.

In some embodiments of the present invention, a processor receiving measurement data may be used to control the transient interaction between the drilling system and the surface of the wellbore. For example, magnetometers, gravitometers, accelerometers, gyroscopic systems and / or the like. can determine amplitude, frequency, speed, acceleration, and / or the like. a drilling system to provide an understanding of any transient motion. Data from the sensors can be sent to the processor for processing, and the parameters of the transient motion of the drilling system can be displayed, used in the control system to control transient interactions of the drill string, processed with other data from the geological formation, wellbore and / or the like. to provide control of a control system for controlling transient drill string interactions and / or the like. By way of example only, the transmission of measurement information to the processor can be carried out by means of a telemetry system, fiber optic cables, cable drill pipes, cable flexible tubing, wireless communication and / or the like.

At step 270, vibratory-type interactions between the drill string and the surface of the wellbore being drilled can be controlled. The interaction between the drill string and the surface of the borehole can be controlled by changing / manipulating / changing the contact characteristics of the bottom section of the drill string, section of the drill string, cutting elements of the drill bit, surface profile of the borehole and / or the like. Contact characteristics may be characteristics associated with the outer surface of the bottom hole assembly section, the drill string section, drill bit cutting elements, and / or the like, which may come into contact with the surface of the wellbore during the drilling process.

Contact characteristics may contain the profile / shape of the external surface (i.e., may contain the characteristics of the eccentric shape of the external surface around the central axis of the drilling system, the layout of the bottom of the drill string, drill bit and / or the like, may contain parameters of the sections of the external surface emerging per caliber and / or indented in caliber), may contain inhomogeneous compliance parameters around the outer surface and / or the like.

At 280, controlled vibratory-type interactions between the drill string and the surface of the wellbore can be used to control the operation / functioning of the drilling system. For example, when it is possible to detect and predict abnormal noise in the drill bit of the drilling system, vibrational interactions between the drill string and the surface of the wellbore can be controlled to eliminate, reduce, and / or prevent abnormal noise. In an embodiment of the present invention, the functionality of the drilling system can be determined from the processed data and can be changed by controlling the interactions between the drill string and the surface of the wellbore. In this way, embodiments of the present invention can create new systems and methods for controlling the operation of drilling systems.

The invention has been described in detail for clarity and understanding. However, it should be clear that some changes and modifications can be made within the scope of the attached claims. Moreover, in the above description, to show various methods and / or procedures, have been described in a specific order. It should be understood that alternative embodiments, methods and / or procedures can be performed in an order different from the above.

Claims (39)

1. The method of using the dynamic movement of the drilling system in the wellbore during drilling or core drilling in the geological formation with a drilling system containing a drill string, a bottom layout and a drill bit to control the drilling system, according to which a section of the drilling system is created to control dynamic interactions between the drilling system and the inner surface of the wellbore, while this section is designed to provide changes to these interactions due to the dyne by moving the drilling system while drilling, around the circumference around the drilling system section and ensuring the creation of these interactions by random dynamic movement of the drilling system in the wellbore, support the specified section without rotation in the wellbore during drilling and use controlled dynamic interactions between the drilling system section and the internal the surface of the wellbore to control the drilling system. 2. The method according to claim 1, wherein when managing dynamic interactions between a section of a drilling system and an inner surface of a wellbore, heterogeneous dynamic interactions between a section of a drilling system and an inner surface of a wellbore are created. 3. The method according to claim 1, wherein when using controlled dynamic interactions between a section of the drilling system and the inner surface of the wellbore, dynamic interactions are used to guide the drilling system. 4. The method according to claim 1, wherein when using controlled dynamic interactions between the section of the drilling system and the inner surface of the wellbore, dynamic interactions are used to control the interaction between the drill bit and the bottom of the well. 5. The method according to claim 1, wherein when using controlled dynamic interactions between the section of the drilling system and the inner surface of the wellbore, dynamic interactions are used to increase the performance of the drill bit. 6. The method according to claim 1, wherein when managing dynamic interactions between the section of the drilling system and the inner surface of the wellbore, an asymmetric section of the drilling system is created. 7. The method according to claim 1, in which when controlling dynamic interactions between a section of the drilling system and the inner surface of the wellbore, a contact element is connected to the drilling system and used to control dynamic interactions. 8. The method according to claim 7, wherein supporting the contact element without rotation in the wellbore during operation of the drilling system. 9. The method of claim 8, wherein the contact element is configured to create a heterogeneous dynamic interaction with the inner surface of the wellbore. 10. The method of claim 8, wherein the contact element has an asymmetric shape. 11. The method according to claim 8, in which the contact element is additionally positioned in the wellbore to ensure the necessary functioning of the drilling system. 12. The method according to claim 11, in which the necessary functioning is the guidance of the drilling system. 13. The method of claim 8, in which the contact element is connected to the layout of the bottom of the drill string. 14. The method of claim 8, wherein the contact element is connected to the drill bit. 15. The method according to claim 8, wherein the contact element is connected to the drilling system to create a condition for the contact element to cycle into contact with the inner surface of the wellbore during the drilling process. 16. The method of claim 8, wherein the contact element is configured to create a change in dynamic interaction between the contact element and the inner surface of the wellbore around the circumference around the contact element. 17. The method of claim 8, wherein the contact element comprises a cylinder eccentrically connected to the bottom of the drill string. 18. The method according to claim 8, in which the contact element is movable on the layout of the bottom of the drill string. 19. The method of claim 8, wherein the contact element is rotatable on the layout of the bottom of the drill string. 20. The method according to claim 8, in which the contact element is connected to the drilling system to ensure the location of the contact element in the cutting circuit of the drill bit. 21. The method of claim 8, in which the contact element is connected to the drilling system to ensure that at least part of the contact element is located outside the cutting contour of the drill bit. 22. The method according to claim 1, wherein the processor is additionally used to control dynamic interactions. - 23 019369 23. The method according to item 22, wherein the processor controls the dynamic interactions in real time. 24. The method according to item 22, in which the processor is additionally used to process the data of the active position of the contact element on the layout of the bottom of the drill string to provide the necessary control of the drilling system and set the contact element in the active position. 25. The method according to item 22, in which additionally register the data and transmit the recorded data to the processor. 26. The method according to item 23, in which the recorded data contains functioning data containing data regarding the operation of at least one functional element of the drilling system. 27. The method according to item 23, in which the recorded data contains data regarding the dynamic movement of the drilling system in the wellbore. 28. The method according to item 23, in which the recorded data contains seismic data related to the geological formation surrounding the wellbore. 29. The method according to item 23, in which the recorded data contains data from the wellbore containing data regarding conditions in the wellbore. 30. A control system for a drilling system for drilling or coring in a geological formation, comprising a drilling system having a drill string, a bottom assembly of the drill string and a drill bit, wherein the wellbore drilled by the drilling system is formed by the inner surface of the wellbore wall and the bottom hole, and an interaction element connected to the drilling system, designed to control dynamic interactions between the drilling system and the inner surface of the wellbore, supported without rashchenija on the drilling system during drilling, which provides for modification of these interactions due to dynamic motion of the drilling system in the wellbore during drilling, circumferentially around the element of interaction and provides randomly create dynamic interactions of said moving the drilling system in the borehole. 31. The system of claim 30, wherein the interaction element is designed to control said dynamic interactions to guide the drilling system. 32. The system of claim 30, wherein the interaction element is designed to control the specified dynamic interactions to control the performance of the drill bit. 33. The system of claim 30, wherein the interaction member is coupled to the drilling system less than 20 feet (6 m) above the drill bit. 34. The system of claim 30, wherein the interaction member is coupled to the bottom of the drill string assembly to create an asymmetric outer profile of the interaction member and the bottom of the drill string. 35. The system of claim 30, further comprising an actuator for moving the interaction member on the drilling system. 36. The system according to clause 35, containing the actuator for rotation of the interaction element on the drilling system. 37. The system of claim 30, further comprising a processor coupled to the actuator and configured to control the actuator to install an interaction element on the drilling system. 38. The system of clause 37, further comprising a sensor for transmitting data to the processor. 39. The system of claim 38, wherein the sensor is one of the following: a geophysical sensor, an accelerometer, a hygroscopic sensor, a temperature sensor, a location sensor, a pressure sensor, a radial motion sensor, a wear sensor.