EA018829B1 - Stochastic bit noise control - Google Patents

Abstract

A drill bit direction system and method is disclosed that modifies or biases the stochastic movement of the drill bit and/or stochastic interactions between the drill bit and an inner- wall of a borehole being drilled by a drilling system to change the direction of drilling of the drilling system. The direction of the drill bit is monitored to determine if the direction happens to align in some way with a preferred direction. If the direction isn't close enough to a preferred direction, a biasing mechanism modifies the stochastic movement in an attempt to modify the direction closer to the preferred direction. Any of a number of biasing mechanisms can be used. Some embodiments can resort to conventional steering mechanisms to supplement the biasing mechanism.

Description

The present invention relates generally to the drilling of a borehole and, but not limited to this, to controlling the direction of drilling of a borehole.

In many industries, it is often desirable to directionally drill a borehole in a formation or drill a coring borehole in subterranean formations so that a borehole and / or core samples can bypass deposits and / or reservoirs in the formation to achieve a given goal in the formation and / or in something like that and / or go through them. When drilling for core sampling or when drilling a borehole in subterranean formations, it is sometimes desirable to be able to change and control the direction of drilling, for example, to direct the borehole to the desired target, or to control the horizontal direction in the hydrocarbon containing area after reaching the target. It may also be desirable to correct deviations from the desired direction when drilling a straight vertical well or to monitor the direction of the well bore in order to eliminate obstacles in the way.

In the production of hydrocarbons, for example, a borehole may be drilled so that it intersects a particular subterranean formation at a specific location. In some drilling methods, in order to drill a given borehole, the drilling trajectory through the formation can be pre-planned, and the drilling system is controlled so that the borehole matches the trajectory. In other methods or in combination with the previous method, final well requirements may be determined, and the course of drilling a well in the formation may be monitored during drilling processes, and steps may be taken to ensure that the specified final requirements for the well are met. In addition, the operation of the drilling system can be monitored to ensure economical drilling, which can include such drilling, to go through the formation as quickly as possible, such drilling to reduce bit wear, such drilling to achieve optimal drilling through the formation and optimal wear chisels and / or the like.

One aspect of drilling is directional drilling. Directional drilling is the intentional deviation of a borehole / borehole from a route that it would take naturally. In other words, directional drilling is the control of the direction of the drill string so that it runs in a given direction.

Directional drilling is advantageous when drilling in the open sea, as it provides drilling of many wells from one platform. Directional drilling also provides horizontal drilling through the reservoir.

Horizontal drilling allows for a longer borehole to pass through the reservoir, which improves the productivity of the well.

The directional drilling system can also be used in vertical drilling operations. Often, the drill bit will deviate from the course of the planned drilling trajectory due to the unpredictable influence of the nature of the passable formations or due to various forces that act on the drill bit. When such a deviation occurs, the directional drilling system is used to return the drill bit back to the course.

The method of monitoring the directional drilling of a borehole may include determining the location of the drill bit in the reservoir, determining the orientation of the drill bit in the reservoir, determining the axial load on the drill bit of the drilling system, determining the drilling rate through the reservoir, determining the characteristics of the drilled formation surrounding the drill bit, prediction of reservoir characteristics before the drill bit, seismic reservoir analysis, reservoir characterization, and so on it, directly at the drill bit, measures pressure, temperature and / or something similar in the borehole and / or around the borehole and / or the like. In any method of directional drilling of a borehole, whether it follows a pre-planned trajectory or not, monitoring the drilling process and / or drilling conditions and / or the like is necessary in order to be able to control the direction of movement of the drilling system.

The forces that act on the drill bit in the drilling method include the force of gravity, the torque generated by the bit, the end load applied to the bit, and the bending moment from the drill unit. These forces, along with the type of reservoir being drilled and the inclination of the reservoir with respect to the wellbore, can create a complex system of force interactions during drilling processes.

A drilling system may comprise a rotary drilling system in which the bottom hole assembly contains a drill bit that connects to a drill string that can be driven / rotated from the drilling platform. In a rotary drilling system, directional drilling of a borehole can be provided by various factors, such as axial load on the bit, rotational speed, and so on.

Regarding rotary drilling, known methods of directional drilling include the use of a rotational orientation system (CB8). In KB8, the drill string rotates from the surface, and downhole devices force the drill bit to drill in a given direction. The rotation of the drill string significantly reduces the number of cases of hanging the drill string

- 1,018,829 or stuck while drilling.

Rotational orientation drilling systems for drilling deviated boreholes in the ground can generally be classified as either bit positioning systems or bit pressure systems. In bit positioning systems, the axis of rotation of the drill bit deviates from the local axis of the bottom-hole equipment (BHA) in the main direction of the new bore. The wellbore is diluted in accordance with the usual three-point geometry, defined by the upper and lower points of contact of the stabilizer and the drill bit. The angle of deviation of the axis of the drill bit in combination with the final distance between the drill bit and the lower stabilizer leads to non-collinear conditions necessary to generate the bend. There are many ways in which this can be achieved, including a fixed bend at some point on the bottom of the drill string equipment closest to the bottom stabilizer, or the bend of the drive shaft of the drill bit, distributed between the upper and lower stabilizer.

Positioning the bit may include using a downhole motor to rotate the drill bit, the motor and the drill bit are mounted on a drill string that contains a bend at some angle. In such a system, the drill bit may be connected to the engine using a loop type mechanism / connection or using a tilting mechanism / joint, a bent transition element or the like, where the drill bit may deviate relative to the engine. When a change in the direction of drilling is necessary, the rotation of the drill string can stop, and the bit can be positioned in the borehole using a downhole motor in the desired direction, and the rotation of the drill bit can start drilling in the desired direction. With this arrangement, the direction of drilling depends on the angular position of the drill string.

In its ideal form, in the bit positioning system, the drill bit does not need to cut the rock in the transverse direction, since the bit axis all the time rotates in the direction of the bend of the wellbore. Examples of adjustable systems such as bit rotational positioning and how they work are described in the publications of US Patent Application Nos. 2002/0011359; 2001/0052428 and in U.S. Pat. Nos. 6,394,193; 6364034; 6244361; 6158529; 6092610 and 5113953, all of which are included in this document as references in its entirety.

Systems and methods for applying pressure to the bit use a pressing force against the borehole wall to bend the drill string and / or force the drill bit to drill in a preferred direction. In the system of rotational orientation with pressure on the bit, the necessary condition of non-collinearity is achieved by forcing the mechanism to apply force or create displacements in a direction that is preferably oriented relative to the direction of breeding of the stem. There are many ways in which this can be achieved, including approaches that do not include rotation (relative to the wellbore), displacement based approaches and eccentric drives that apply force to the drill bit in the direction of rotation required. In addition, rotation is achieved by creating a non-collinear between the drill bit and at least two other touch points. In its ideal form, the drill bit requires cutting the sides to create a curved wellbore. Examples of rotary swivel systems with pressure on the bit, and how they work, are described in US Pat. Nos. 5,265,682; 5553678; 5803185; 6089332; 5695015; 5,685,379; 5706905; 5553679; 5673763; 5,520,255; 5603385; 5582259; 5778992; 5971085, they are all included as references in this document.

Known forms of CB8 are supplied with a reverse rotation mechanism, which rotates in the opposite direction to the rotation of the drill string. Typically, the reverse rotation occurs at the same speed as the rotation of the drill string, so that the section with reverse rotation is maintained in the same inclined position relative to the inside of the borehole. Since the section with reverse rotation does not rotate relative to the borehole, it is often referred to as geostationary by specialists in this field. In the present invention, no distinction is made between the term rotating in the opposite direction and geostationary.

The system of pressure on the chisel, as a rule, uses either an internal or external stabilizer of reverse rotation. Stabilizer reverse rotation remains at a fixed angle (or geostationary) relative to the borehole wall. When the borehole must deflect, the actuator pushes the shoe away from the borehole wall in the direction opposite to the desired deflection. The result is that the drill bit is pushed in the desired direction.

The forces generated by the drives / shoes are compensated for by the bending force of the bottom string equipment, and the force causes a response by drives / shoes on the opposite side of the bottom string equipment, and the counter force acts on the cutting elements of the drill bit, thereby controlling the direction of the borehole. In some situations, the force of the shoes / actuators may be large enough to erode the formation where the system is used.

For example, the BCIT system ™ uses three pads mounted around the drill string equipment section for synchronous use of the drill string equipment to push the bit in its direction and control the drilled drilling rig.

- 2,018,829 well. In this system, the shoes are fastened close, in the range of 1-4 feet (30.48-121.9 cm), and driven by the bit and driven by the flow of drilling fluid taken from the flushing fluid. In other systems, the axial load on the bit created by the drilling system, or a deflection wedge, or something similar, can be used to orient the drilling system in the borehole.

Although the system and methods for applying force to the borehole wall and using reaction forces to push the drill bit in a certain direction or to move the drill bit in the desired direction can be used with drilling systems containing a rotary drilling system, these systems and methods may have drawbacks. For example, such systems and methods may require large forces to be applied to the borehole wall in order 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; this may require large / complex downhole motors or the like to obtain these efforts. In addition, a variety of systems and methods can use repetitive thrust pressure of the shoes / actuator in the direction from the axis to the borehole wall when the bottom of the drill string rotates to form opposing forces to push the drill bit, which may require complicated / expensive / requiring high operating costs of synchronization systems requiring complex control systems and / or the like.

A drill bit, as is known, performs a dance or circular beats in a borehole in an unpredictable or even erratic way. This stochastic motion is generally non-deterministic in the sense that the current position does not completely determine its next position. Technology positioning bits and pressure on the bit are used to guide the drill bit in a certain direction and to overcome the tendency of the drill bit to commit circular beats. These technologies do not take into account the stochastic dance of the drill bit, which is likely in the absence of a directed effort.

Summary of Invention

In one embodiment, the present invention provides a drill bit guide system that alters or rejects stochastic or natural movement of the drill bit and / or stochastic counter-resistance efforts between the drill bit and / or gauge shoes and the inner wall of the drilled hole to change the direction of drilling. Changing the direction of drilling may in certain aspects be achieved with less effort, less complex surface / underground equipment and / or more economically than with traditional directional control devices. The direction of the drill bit relative to the ground (or some other fixed point) is monitored to determine if the direction aligns with some preferred direction. If the direction is not close enough to the preferred direction, the deflecting mechanism highlights the components of the radial movement to move the direction closer to the preferred direction. Any number of deflecting mechanisms may be used. Some embodiments may resort to conventional directional control devices in addition to or alternatives to the deflecting mechanism.

In another embodiment, a method for deflecting an erroneous movement of a drill bit is described in order to force the bit to drill in a given direction relative to the ground. At the same time, the direction of the drill bit relative to the ground is determined, the determined direction is compared with the specified direction. The deflecting mechanism is oriented to isolate the components of the radial movement of the drill bit in a given direction. The deflecting mechanism is triggered when, when compared, it is determined that the determined direction does not sufficiently coincide with the specified direction.

In another embodiment, a guide system for a drill bit is proposed to deflect erroneous movement of the drill bit in order to force the bit to drill in a given direction relative to the ground. The guide system for the drill bit contains a deflecting mechanism, a direction sensor and a controller. The deflecting mechanism highlights the components of the radial movement of the drill bit in a given direction of the drill bit relative to the ground. The direction sensor determines the direction of the drill bit inside the well. The controller compares the specified direction with the direction of deviation. The deflecting mechanism is activated when the direction deviates from the given direction.

Additional areas of applicability of the present invention will be apparent from the detailed description given later in this document. It should be understood that the detailed description and specific examples, while showing various embodiments, are intended for purposes of illustration only and are not intended to necessarily restrict the scope of the invention.

Brief Description of the Drawings

The present invention is described in conjunction with the accompanying drawings, in which FIG. 1 is a block diagram of an embodiment of a guide system for a drill bit;

- 3 018829 of FIG. 2A and 2C is a block diagram of embodiments of a method for monitoring the direction of a drill bit; FIG. 3A and 3C are a state machine for controlling a guide system for a drill bit.

In the accompanying drawings, similar components and / or functions may have similar reference numbers. Also, different components of the same type can be allocated a reference number followed by a hatching and a second reference number by which they differ for similar components. If only the first reference number is used in the description, the description applies to any similar components having the same first reference number, regardless of the second reference number.

Detailed Description of the Invention

The following description provides for a preferred exemplary embodiment only (embodiments) and is not intended to limit the use or configuration of the invention. Rather, the following description of a preferred exemplary embodiment (embodiments) will provide those skilled in the art with a guide description for implementing the preferred exemplary embodiment. It is obvious that various changes in the function and organization of the elements can be made without departing from its spirit and scope, as set forth in the appended claims.

Turning first to FIG. 1, a block diagram of one embodiment of a guiding system for a drill bit 100 is shown here. The integrated control and information service (1C18) 104 is located in the ground structures to control the rotation control unit of the drill string 112 and the drawworks control unit 108. In addition to this , 1C18 104, as a rule, directs the direction of drilling in the reservoir.

Information is transmitted to the well at the bottom of the drill string (BHA) equipment 120 in order to achieve the desired orientation or direction for the drill bit and for the possible selection of various deflecting devices and directional control devices 132, 136 for use. The direction is determined relative to any fixed point, such as the ground. The information may, in addition to this, provide control information for the VNA 120 and for any deflecting devices and directional control devices 132, 136.

1C18 104 controls the control unit of rotation of the drill string 112 and the control unit of the drawworks 108. The phase, torque and speed of rotation of the drill string are monitored and controlled by the control unit of the drill string 112. Information from BHA 120 can be analyzed using 1C18 104 as a negative feedback how to control the control unit of the drill string 112. Various operations while drilling use the control unit of the winch 108, for example, when removing the drill string. 1C18 104 controls the operation of the control unit of the winch 108 during these operations.

BHA 120 includes a downhole controller 124, an orientation or direction sensor 128, a bit rotation sensor 140, one or more deflecting mechanisms 132, and one or more directional control devices 136. A typical BHA may have more monitoring systems that are not shown in FIG. 1. Information is transmitted to the VNA 120 from the surface to indicate the preferred direction of the drill bit. In addition to this, the use of deflecting devices and directional control devices 132, 136 can usually be controlled using 1C18 104, but the downhole controller 124 controls in real time the operation of the deflecting devices and directional control devices 132, 136 using information collected from the bit direction sensors and bit rotation sensors 128, 140.

Information is transmitted from the VNA 120 back to the 1C18 104 on the surface. The observed direction of the drill bit can be periodically transmitted along using various deflection means and directional control devices 132, 136. The drill route information database 116 stores information gathered inside the well to know how the well is laid in the formation. The 1C18 104 can recalculate the best orientation or direction used by the drill bit and transfer this to the VNA 120 to reconfigure the previous instructions.

In addition, the effectiveness of various deflection means and directional control devices 132, 136 can be analyzed using other information gathered in the reservoir to create instructions for downhole equipment on how best to use available deflection means and directional control device 132, 136 to achieve the geometry of the borehole desired for a particular drilling site.

The direction sensor 128 can determine the current direction of the drill bit relative to a particular coordinate system in three dimensions (that is, relative to the ground or some other fixed point). Different technologies can be used to determine the current direction, for example platforms stabilized by inertia, or platforms stabilized by rotation using gyroscopes can be compared with the standards on the drill bit, accelerometers can be used to track the direction and / or magnetometers can measure the direction relative to the earth’s magnetic field . Measurements may be obstructed by noise, but a filter may be used.

- 4,018,829 to eliminate noise through signal accumulation from measurements.

The bit rotation sensor 140 provides the ability to monitor the phase of rotation of the drill bit. The downhole controller 124 receives information from the sensor to enable synchronized control of the diverting mechanism (s) 132. Knowing the phase, the deflection means can be applied on each rotation cycle or through any integer number of cycles (for example, every second revolution, every third revolution, every fourth revolution every tenth turn and so on). Other embodiments do not use the bit rotation sensor 140 or the timing manipulation by the diverting mechanism (s) 132.

There are various mechanisms for controlling the direction of motion 136, which have a steady effect on the movement of the drill bit. The directional control devices 136 inadvertently take advantage of the stochastic movement of the drill bit, which occurs naturally. On this site, one or more of these directional control devices 136 may be used to create a borehole that changes the direction of passage through the formation as desired. The various types of directional control devices 136 include curved tonearms, a lever arm synchronized with rotation, universal connections, and geostationary mechanisms that make efforts in a particular direction. These directional control devices can predictably direct the drill bit, but do not take advantage of the stochastic movement of the drill bit, which may accidentally be in the right direction. Other embodiments may opt out of directional control devices 136, based entirely on deflecting mechanisms 132 for directional drilling.

The deflecting mechanism 132 may be used before referring to the directional control device 136. The deflecting mechanism 132 selects or highlights those components of the radial movement of the drill bit that are in the selected direction. Directional control is achieved by keeping the orientation of the deflection mechanism 132 approximately fixed in the chosen direction. Some embodiments within the well may have only one or a few deflecting mechanisms 132 without any directional control devices 136. The deflecting mechanisms 132 take advantage of the tendency of the drill bit to move in a circle in the wellbore, they are activated only when stochastic movement going in the wrong direction. For example, measuring shoes or cutting elements may move, a calibrator may exert pressure, and / or jetting drilling may be used in various embodiments as a deflecting mechanism 132. Any manipulative asymmetry is useful as a deflecting mechanism 132. In some cases, the drill bit is designed and manufactured so as to cause a clamping force in a particular azimuthal direction relative to the drill bit. The deflecting mechanism 132 is actuated to deflect the downforce. This clamping force rotates with the drill bit to highlight the cutting in the selected direction. The bias mechanism 132 may be synchronized to turn on and off as the drill bit rotates.

The downhole controller 124 uses information that is sent from 1C18 104, along with bit direction and rotation sensors 128, 140, to actively control the use of deflection tools and directional control devices 132, 136. The desired direction of the drill bit along with instructions for using various deflection tools and the directional control devices 132, 136 are transmitted from 1C18 104. The downhole controller 124 may use fuzzy logic, neural algorithms, algorithms of systems with state of mind for making decisions about how and when to influence the direction of the drill bit in various embodiments. In general, the interaction speed between BHA 120 and 1C18 104 does not provide real-time control from the surface in this embodiment, but other embodiments may provide real-time control from the surface. The stochastic direction of the drill bit can be used in an adaptive, less rigid way. For example, if a borehole turn is desirable in the future and the drill bit makes this turn prematurely, the turn may be accepted and the plan for the future is revised.

FIG. 2A shows a block diagram of an embodiment of a method 200-1 for controlling the direction of a drill bit. This embodiment uses only one deflection mechanism 136 to control the direction of the drill bit. The depicted portion of the method is located at block 204 where a formation and end point analysis is performed to plan the geometry of the borehole. The 1C18 104 manipulates the drill string, winch, and other systems in block 208 to create a borehole according to plan. The desired direction of the drill bit is determined in block 212 and communicated to the downhole controller 124 in block 216. The desired direction may be a single target or a number of acceptable directions.

The desired direction, along with any criteria for choosing the deviation means, is taken by the downhole controller 124 in block 220. The current positioning of the drill bit is determined

- 5 018829 of the direction sensor 128 in block 224. Whether the direction is acceptable based on instructions from 1C18 104 is determined in block 228. This embodiment allows some flexibility in direction and redefines the plan based on stochastic motion, allowing for its implementation. An acceptable direction is one that provides an opportunity to reach the end point with a drill bit if the plan has been revised. A specific plan may have specified deviations or a range of directions that are acceptable, but still removes from the path of the part of the reservoir, through which it is undesirable to pass.

Where the direction is unacceptable, processing proceeds from block 228 to block 236, where the deflecting mechanism 132 is actuated. The deflecting mechanism 132 may be activated once or for a period of time. Alternatively, the deflecting mechanism 132 may operate periodically in synchronization with the rotation of the drill bit. The deflecting mechanism 132 selects or highlights those components of the radial movement of the drill bit that are carried out in the desired direction (s).

Where the direction is acceptable, as determined in block 228, processing continues to block 240. The deflection mechanism 132 achieves directional control by keeping the direction in the desired direction (s). Where this is not necessary, since the erroneous movement of the drill bit is already among the desired directions, the deflecting mechanism 132 is not activated. In block 240, the current direction is transmitted using the downhole controller 124 on the 1C18 104. After the message, processing returns to the beginning of the cycle to block 212 to further control the direction based on any new surface instruction.

FIG. 2B is a block diagram of another embodiment of a method 200-2 for controlling the direction of a drill bit. This embodiment has many available deflecting mechanisms 132 and may resort to directional control devices 136 if the deflecting mechanism (s) 132 is ineffective. Blocks up to block 228 typically operate in the same way as the embodiment of FIG. 2A. When the direction is unacceptable in block 228, processing proceeds to block 232, where a selection is made from at least two deflecting mechanisms 232. Instructions from 1C18 104 may prescribe a decision as to which deflecting mechanisms 132 to choose and how they should be controlled or affected him The selected deflection mechanism 132 is used in step 236.

After using the deflector 132, the current direction is reported to 1C18 104 in block 240. If the deflector 132 or some other deflecting mechanism is still supposed to be effective for orienting the drill bit in block 244, the processing returns to the beginning of the cycle to block 212 to continue using this deflecting mechanism 132 or any other deflecting mechanism 132 that may affect these components of the radial movement of the drill bit to apply his efforts in a particular azimuth direction, as desired. When the deflecting mechanisms 132 are determined in block 244 as already inefficient, processing proceeds to block 248 to turn on the directional control device 136, if any.

FIG. 2C shows a block diagram of another embodiment of a method 200-3 for controlling the direction of a drill bit. This embodiment is an embodiment similar to that of FIG. 2A, except that in block 232, a plurality of deflection mechanisms 132 can be selected. This embodiment is based on the deflection mechanism 132 without recourse to directional control devices 136.

FIG. 3A shows one of the embodiments of the finite state machine 300-1 for controlling the guide system for the drill bit 100. This control system moves between two positions based on determining in position 304 whether the drill bit is in alignment with the desired direction or range of directions. This embodiment corresponds to the embodiment of FIG. 2A. Where there is disorientation beyond the acceptable deviation, the guide system for the drill bit 100 moves from position 304 to position 308. At position 308, one or more deflecting mechanisms try to actuate 132. In some cases, the same deflecting mechanism 132 try to actuate with other parameters. For example, the control shoe can move with one phase in the bit rotation cycle, but later try to set another phase with the same or different movement of the control shoe.

FIG. 3B, another embodiment of a finite state machine 300-2 for controlling a guide system for a drill bit 100 is shown. This embodiment has four positions and generally corresponds to the embodiment of FIG. 2B. After attempting to turn on the deflection mechanism 132 at position 308, the definition at position 312 is used to see if the deflection mechanism 132 was effective. When the deflection mechanism 132 works satisfactorily, the system returns to position 304. If the deflector mechanism 132 is ineffective, the guide the system for the drill bit 100 moves from position 312 to position 316, where the active directional control device 136 is used before returning to position 304.

- 6 018829

FIG. 3C, another embodiment of a finite state machine 300-3 for controlling a guide system for a drill bit 100 is shown. This embodiment has a number of deflection technologies and generally relates to the method 200-3 in FIG. 2C. When disorientation is detected at position 304, a deflection mechanism or deflection technique is selected at position 312. Alternatively, at position 312, a number of deflection technologies may be selected. The selected deviation technology is carried out at the selected deviation position 320 before returning to position 304 for further analysis of any disorientation.

A number of variations and modifications of the described embodiments may also be used. For example, the invention may be used in drilling boreholes or core boreholes. In the embodiments described above, the control of deflection methods is divided between 1C18 and BHA. In other embodiments, the entire control may be in any of the locations.

In the description above, specific details are provided in order to provide a thorough understanding of the embodiments. Although it is obvious that embodiments may be carried out without these specific details. For example, circuit diagrams may be shown in block diagrams in order not to obscure embodiments in unnecessary detail. In other examples, well-known circuitry, methods, algorithms, structures, and technologies may be shown without undue detail to avoid obscuring the embodiments.

The implementation of technologies, blocks, stages and the means described above can occur in various ways. For example, these technologies, blocks, stages, means may be implemented in hardware, software, or in their combination. For the hardware implementation of the installation for processing can be embodied in one or more specialized integrated circuits (A81C). digital signal processors (Ό8Ρ), digital signal processing devices (Ό8ΡΌ), programmable logic devices (РЬЭ), user-programmable logic arrays (РРСА), processors, controllers, microcontrollers, microprocessors, other electronic devices designed to perform the functions described above and / or in their combinations.

Also note that the embodiments may be described as a method that is described as a block diagram, a circuit diagram, a block diagram of an algorithm, a block diagram, or an algorithm. Although the flowchart may describe operations as a multi-step process, multiple operations can be performed in parallel or in series. In addition to this, the order of operations can be redistributed. The method is terminated when its operations end, but it may have additional stages not included in the drawings. A method may correspond to a method, a function, a procedure, a subprogram, a part of a program, and so on. When a method matches a function, its completion corresponds to the return of the function to the calling function or to the main function.

In addition, embodiments may be implemented in hardware, software, scripting languages, software and hardware, middleware, microinstruction, hardware description language, and / or any combination thereof. When implemented by hardware, software, scripting languages, firmware, cross-platform software, microinstruction, software code or code segments to perform the necessary tasks can be stored on machine-readable media, such as storage media. A code segment or instruction executed by a machine can be a procedure, a function, a subroutine, a program, a sequence, a standard subroutine, a module, a software package, a script, a class, or any combination of instructions, data structures, and / or program statements. A code segment can be connected to another code segment or hardware circuit by passing and / or receiving information, data, arguments, parameters, and / or memory contents. Information, arguments, parameters, data, and so on can be passed, sent, or transmitted through any suitable means, including memory sharing, message passing, relay access, network transmission, and so on.

For software and hardware implementation and / or software implementation, the methodology can be implemented using modules (for example, procedures, functions, and so on) that perform the functions described in this document. Any machine-readable media that implements the instructions can be used to implement the methodologies described in this document. For example, program codes may be stored in memory. Memory can be implemented in the processor or outside the processor. As used herein, the term memory refers to any type of long-term, short-term, non-permanent, non-volatile, or other storage medium and is not limited to any particular type of memory or amount of memory or type of media on which the memory is stored.

In addition, as described in this document, the term “storage medium” can represent one or several memory modules for storing data, including read-only memory (KOM), random-access memory (KAM), magnetic QAM, memory device on magnetic cores. , storage devices on magnetic disks, optical data storage devices, flash memory devices and / or other computer-readable media for storing information. The term machine-readable media includes, but is not limited to, portable or stationary storage devices, optical storage devices, wireless channels and / or other various information storage media that contain or carry instructions (instructions) and / or data.

Although the principles of the invention are described above in connection with specific devices and methods, it is necessary to clearly understand that the present description is given solely as an example and does not limit the scope of the invention.

Claims (8)

CLAIM 1. The method of rejecting the erroneous movement of the drill bit bottom of the drill string while drilling a well in the formation in a given direction, according to which determine the direction of drilling relative to the formation; comparing direction with a given direction; using a deflecting mechanism, which is configured to allocate radial erroneous movement of the equipment of the bottom of the drill string in a given direction; and orient the deflecting mechanism, if during comparison it is determined that the direction does not coincide with the given direction, moreover, a measuring shoe is used as the deflecting mechanism, asymmetrically connected to the equipment of the bottom of the drill string and held in a fixed direction. 2. The method according to claim 1, according to which, to make the bit directed to drill in a predetermined direction relative to the ground, the drill bit is made with the possibility of applying a rotational lateral force along some fixed direction relative to the drill bit, and the deflecting mechanism is configured to deflect the rotational lateral force, as a result, the drill bit tends to turn to a given direction. 3. The method according to claim 1, according to which, in order to make the bit directed to drill in a predetermined direction relative to the ground, an additional directional control device is used, under the influence of which the direction of the drill bit is changed, while the directional control device is a bit positioning mechanism. 4. The method according to claim 1, according to which, in order to make the bit directed to drill in a predetermined direction relative to the ground, a predetermined direction is additionally reported from ground structures. 5. A guide system for the drill bit to reject erroneous movement of the drill bit to force the bit to directed drill in a predetermined direction relative to the formation, the guide system for the drill bit comprising a bottom of the drill string with a drill bit; a deflecting mechanism for isolating components of the radial erroneous movement of the drill bit in a predetermined direction relative to the formation, wherein a movable measuring shoe is used as a deflecting mechanism, asymmetrically connected to the bottom equipment of the drill string and held in a fixed direction; a direction sensor for determining the direction of the well with the drill bit, a controller for comparing the predetermined direction with the specified direction, providing the possibility of orienting the deflecting mechanism to highlight the components of erroneous movement in the determined direction, if the controller determines that the direction does not coincide with the specified direction. 6. The guiding system according to claim 5, in which the drill bit is made with the possibility of applying a rotational lateral force along a fixed direction relative to the drill bit and the deflecting mechanism is configured to deflect the rotational lateral force, as a result of which the drill bit tends to rotate to a predetermined direction. 7. The guiding system according to claim 5, in which the controller is located in the well. 8. The guiding system according to claim 5, which is configured to set a given direction on the surface and communicate it to the bottom equipment of the drill string.