RU2708444C2 - Drilling bit with self-regulating platforms - Google Patents

Abstract

FIELD: soil or rock drilling; mining.

SUBSTANCE: group of inventions relates to downhole tool of rotary drilling and to method of well drilling. Downhole rotary drilling tool comprises tool housing; self-regulating element made with possibility of extension and retraction, connected with tool body and at least partially protruding above tool body surface; speed control device connected to element. Speed control device is configured to cause the element to move outward relative to the tool body from the retracted position to the extended position at the first speed in the absence of application of the external force to the element. Speed control device is configured to cause the element to move inward relative to the tool body from the extended position to the retracted position at the second speed in response to application to the external force element. Second speed differs from first speed, and speed control device comprises piston to apply force to element; a biasing member configured to apply force to the element extension piston; fluid chamber connected to piston; and a pressure control device for controlling fluid pressure inside the fluid chamber.

EFFECT: technical result consists in providing a smoother surface of the borehole, preventing early damage of the cutters and longer service life of the drill bit by controlling the rate of change of instantaneous depth of cutting of the drill bit.

20 cl, 15 dwg

Description

CLAIM FOR PRIORITY

This application claims priority with respect to the filing date of US patent application No. 14/864436, filed September 24, 2015, under the name "DRILL BIT WITH SELF-ADJUSTING PADS", which is a continuing application for US patent application No. 14/516340 October 16, 2014, which is partly a continuation of patent application US No. 13/864926, filed April 17, 2013, each of which is incorporated herein in full by reference.

FIELD OF TECHNOLOGY

The present invention relates generally to drill bits and systems using drill bits for drilling wellbores.

BACKGROUND

Oil wells (also called “boreholes” or “boreholes”) are drilled using a drill string containing a tubular element with a drill string (also called “bottom hole assembly” or “BHA”). BHA usually contains devices and sensors that provide information related to a variety of parameters related to drilling (“drilling mode parameters”), BHA behavior (“BHA parameters”), and also parameters relating to the formation surrounding the wellbore (“reservoir parameters” ) A drill bit attached to the lower end of the BHA rotates by rotating the drill string and / or the drill motor (also called the “downhole motor”) in the BHA to crush the rock formation for drilling the wellbore. A large number of boreholes are drilled along contour paths. For example, one borehole may contain one or more vertical sections deviated from the vertical sections and horizontal sections passing through various types of rock formations. When switching from drilling a soft formation, such as sand, to drilling a hard formation, such as shale, or vice versa, the mechanical penetration rate (SMF) changes and can cause (with a decrease or increase) excessive vibrations or vibration (lateral or torsion) of the drill bit . The MRP is typically controlled by controlling the axial load on the bit and the rotational speed (in revolutions per minute or “rpm”) of the drill bit to control the oscillations of the drill bit. BOP is controlled by controlling the load on the hook on the surface, and the number of revolutions per minute is controlled by controlling the rotation of the drill string on the surface and / or by controlling the speed of rotation of the downhole motor in the BHA. Managing vibrations and the number of revolutions per minute of the drill bit in such ways requires the surface of the drilling system or operator to perform certain actions. The effect of such actions on the surface on the oscillations of the drill bit is not instantaneous. Aggressiveness of the drill bit increases vibration, runout and intermittent movement at specific drill bits and rotation speed of the drill bit. The “depth of cut” (GR) of the drill bit, usually defined as “the distance the drill bit is axially recessed into the formation in one revolution,” is a related factor related to the aggressiveness of the drill bit. GR management can provide a smoother borehole, help prevent premature damage to the cutters, and extend the life of the drill bit.

The invention disclosed herein provides a drill bit and drilling systems using it, configured to control the rate of change of the instantaneous GR of the drill bit while drilling a well.

SUMMARY OF THE INVENTION

In one aspect, a drill bit is disclosed, comprising: a bit body; platform associated with the body of the bit; a speed control device attached to the platform extending from the surface of the bit at the first speed and retracting from the extended position to the retracted position at the second speed in response to an external force acting on the platform, the speed control device comprising: a piston for applying force to the platform; a biasing element configured to apply force to the piston to extend the platform at a first speed; fluid chamber associated with the piston; and a pressure control device for monitoring fluid pressure within the fluid chamber.

In another aspect, a method for drilling wells is disclosed, comprising: providing a drill bit comprising a bit body, a pad associated with the bit body, and speed control devices; the introduction of the drill string into the formation, and the drill string has at its end a drill bit; selectively extending the platform from the surface of the bit at a first speed using a speed control device; selectively retracting from the extended position to the retracted position at a second speed in response to an external force applied to the site through the speed control device; a speed control device comprising: a piston for applying force to a site; a biasing element configured to apply force to the piston to extend the platform at a first speed; fluid chamber associated with the piston; as well as controlling fluid pressure inside the fluid chamber using a pressure control device; and drilling using a drill string.

In yet another aspect, a system for drilling wells is disclosed, comprising: a drill having a drill bit, which comprises: a bit body; platform associated with the body of the bit; a speed control device attached to the platform extending from the surface of the bit at the first speed and retracting from the extended position to the retracted position at the second speed in response to an external force acting on the platform, the speed control device comprising: a piston for applying force to the platform; a biasing element configured to apply force to the piston to extend the platform at a first speed; fluid chamber associated with the piston; and a pressure control device for monitoring fluid pressure within the fluid chamber.

In yet another aspect, a drill bit is disclosed, comprising: a bit body; platform associated with the body of the bit; a speed control device attached to the platform extending from the surface of the bit at the first speed and retracting from the extended position to the retracted position at the second speed in response to external force, the speed control device comprising: a piston for applying force to the platform; a biasing element configured to apply force to the piston to open the pad at a first speed; and a rotary device configured to apply force to the piston to conceal the site at a second speed.

Examples of some of the device functions and the method described herein are given sufficiently broadly to better understand their subsequent detailed description. Of course, there are additional functions of the device and method, described later in this document, which will be the subject of the claims contained in this document.

BRIEF DESCRIPTION OF GRAPHIC MATERIALS

The information disclosed in this document is easiest to understand, referring to the accompanying graphic materials on which the same numbers denote the same elements, and within which:

in FIG. 1 is a schematic illustration of an example of a drilling system comprising a drill string having a drill bit manufactured in accordance with one embodiment of the present invention;

in FIG. 2 illustrates a partial cross-sectional view of an example of a drill bit with a pad and a speed control device for controlling the speed of extension and retraction of the pad from the surface of the drill bit in accordance with one embodiment of the present invention;

in FIG. 3 illustrates an alternative embodiment of a speed control device defining site actions through a hydraulic line;

in FIG. 4 illustrates an embodiment of a speed control device configured to control multiple sites;

in FIG. 5 illustrates the arrangement of the speed control device of FIG. 3 in a section of a drill bit crown;

in FIG. 6 illustrates the placement of a speed control device in a flushing groove or in a flow path of a drill bit;

in FIG. 7 illustrates a drill bit in which the speed control device and platform are located on the outer surface of the drill bit;

in FIG. 8A, an embodiment of a speed control device with a multi-chamber outlet is illustrated;

in FIG. 8B illustrates an embodiment of a multi-chamber outlet for use with the speed control device illustrated in FIG. 8A;

in FIG. 9 illustrates an embodiment of a speed control device with a high-precision clearance;

in FIG. 10 illustrates an embodiment of a speed control device configured to control multiple sites;

in FIG. 11 illustrates an embodiment of a speed control device configured to extend from a center of a bit;

in FIG. 12 illustrates an embodiment of a speed control device with a multi-wall camera;

in FIG. 13 illustrates an embodiment of a speed control device with a compensation piston;

in FIG. 14 illustrates an embodiment of a speed control device with a rotary device; and

in FIG. 15 illustrates an alternative embodiment of a speed control device.

OPTION (S) FOR CARRYING OUT THE INVENTION

In FIG. 1 is a schematic illustration of an example of a drilling system 100 in which drill bits made in accordance with the invention disclosed herein can be used. In FIG. 1 illustrates a wellbore 110 comprising an upper section 111 with a casing 112 installed therein and a lower section 114 that is drilled using a drill string 118. Drill string 118 is illustrated containing a tubular member 116 with BHA 130 attached to its lower end. Tubular member 116 may be obtained by connecting drill pipe sections or may be a flexible tubing. Drill bit 150 is illustrated attached to the lower end of BHA 130 s for crushing rock formation 119 for drilling a borehole 110 of a selected diameter.

Drill string 118 is illustrated being inserted into the wellbore 110 from a drilling rig 180 at surface 167. An illustrated example of a drilling rig 180 is a surface drilling rig for ease of explanation. The device and methods disclosed herein can be applied to an offshore drilling rig used to drill wells underwater. A rotary table 169 or a top drive (not illustrated) connected to the drill string 118 can be used to rotate the drill string 118 to rotate the BHA 130 and thus the drill bit 150 to drill the borehole 110. The drill motor 155 (also called the downhole motor ) can be provided in BHA 130 for rotating the drill bit 150. The drilling engine 155 can be used autonomously to rotate the drill bit 150 or for applying rotation of the drill bit to the drill string 118. The control unit (or controller ) 190, which can be a computer-based control unit, can be located on surface 167 to receive and process data transmitted by drill bit sensors 150 and sensors on BHA 130, as well as to control selected actions of various BHA 130 sensors and sensors. Located on surface controller 190 in one embodiment may include a processor 192, a storage device (or computer readable medium) 194 for storing data, algorithms, and computer programs 196. With such a device x Anenij data 194 may be any suitable device, including a read only memory (ROM), a random access memory (RAM), flash memory, magnetic tape, hard disk, optical disk, but is not limited thereto. During drilling, fluid 179 from its source is pumped under pressure into tubular member 116. Fluid is discharged at the bottom of drill bit 150 and returns to the surface through an annular space (also called “annulus”) between drill string 118 and inner wall 142 of wellbore 110 .

BHA 130 may further comprise one or more downhole sensors (which are collectively indicated by 175). Sensors 175 may include any number and type of sensors, including, but not limited to, sensors commonly known as measurement sensors while drilling (IVB) or logging while drilling (CVB), and sensors that provide information regarding the operating mode of the BHA 130, for example , rotation of the drill bit (revolutions per minute or “rpm”), the end face of the bit, pressure, vibration, vortex, runout and spasmodic movement. The BHA 130 may further comprise a control unit (or controller) 170 that controls the actions of one or more BHA 130 devices and sensors. The controller 170 may include, inter alia, circuits for processing signals from the sensor 175, a processor 172 (such as a microprocessor) for processing the digitized signals, a data storage device 174 (such as solid state memory) and a computer program 176. A processor 172 can process digitized signals and control downhole devices and sensors, as well as exchange data with ler 190 through a telemetry unit with a two-way data line 188.

As illustrated in FIG. 1, the drill bit 150 comprises a front face (or bottom face) 152. During drilling, the front face 152 or a portion thereof is turned toward the formation in front of the drill bit or to the bottom of the wellbore. Drill bit 150 in one aspect comprises one or more platforms 160 that are capable of extending and retracting from a selected surface of drill bit 150. As used herein, platforms 160 are also referred to as “extension platforms”, “extension platforms” or “adjustable platforms”. A suitable actuator (or drive unit) 165 of the drill bit 150 may be used to extend and retract one or more sites from the surface of the drill bit while drilling the wellbore 110. In one aspect, the actuator 165 may control the speed of the telescope 160 to extend and retract. the mechanism is also called a “speed control device” or a “speed controller”. In another aspect, the actuator is a passive device configured to automatically correct or independently adjust the extension and retraction of the pad 160 based on or in response to the impact on the pad 160 of force or pressure during drilling. In certain embodiments of the invention, actuator 165 and pad 160 are driven by contact with the formation. In addition, with a rapid change in the depth of cut of the drill bit 150, significant force acts on the sites 160. Accordingly, it is desirable that the actuator 165 withstand changes in the depth of cut. In certain embodiments of the invention, the actuator 165 increases the load on the bit at a certain cutting depth. In other embodiments of the invention, actuator 165 reduces the depth of cut for a particular bit load. The speed of the platform extension and retraction can be set in advance, as described in more detail with reference to FIG. 2-4.

In FIG. 2 illustrates an example of a drill bit 200 manufactured in accordance with one embodiment of the present invention. In an example embodiment, the drill bit 200 is a polycrystalline diamond bit (PDC) with a bit body 201 comprising a recess or neck section 210, a neck 220, and a crown or crown section 230. In other embodiments, the drill bit 200 is any suitable drill bit a chisel or formation removal device for use in the formation. In other embodiments, the drill bit 200 is any suitable downhole rotary tool. The neck 210 has a tapered upper edge 212 with a thread 212a for attaching the drill bit 200 to the closed head of the drill 130 (Fig. 1). The neck 220 has a lower vertical or straight section 222 rigidly connected to the crown 230 at the junction 224. The crown 230 comprises a front face or front section 232 facing the formation while drilling. The crown 230 contains a number of blades, such as blades 234a, 234b, etc. A typical PDC bit contains 3-7 blades. Each blade has a front face (also called a “front section”) and a sidewall (also called a “side section”). For example, the blade 234a has a front face 232a and a sidewall 236a, while the blade 234b has a front face 232b and a sidewall 236b. The sides 236a and 236b are located along the longitudinal or vertical axis 202 of the drill bit 200. Each blade further comprises a series of incisors. In the specific embodiment of FIG. 2, a blade 234a is illustrated as having cutters 238a on a portion of a sidewall 236a and cutters 238b along a front edge 232a, while a blade 234b is shown as containing cutters 239a on a sidewall 239a and cutters 239b on a front edge 232b.

As illustrated in FIG. 2, the drill bit 200 comprises one or more elements (also referred to herein as pads) configured to extend and retract from the surface 252 of the drill bit 200. In FIG. 2 illustrates a platform 250 that is movably positioned in a cavity or recess 254 in a crown section 230. A switch 260 may be coupled to a platform 250 to extend and retract the block 250 from a location on the surface of the drill bit 252. In one aspect, the switch 260 controls speed extending and retracting the pad 250. In another aspect, the device 260 extends the pad at a first speed and retracts the pad at a second speed. In embodiments of the invention, the first speed and the second speed may be the same or different speeds. In yet another aspect, the extension speed of the pad 250 may be greater than the retraction speed. As previously noted, device 260 is also referred to herein as a “speed control device” or “speed controller”. In a particular embodiment of the device 260, the pad 250 is directly connected to the device 260 via a mechanical connection or a connecting member 256. In one aspect, the device 260 comprises a chamber 270 comprising a double acting reciprocating element, such as a piston 280 that seals the chamber 270 to a first chamber 272 and a second chamber or reservoir 274. Both chambers 272 and 274 are filled with hydraulic fluid 278 suitable for use in a well, such as oil. A biasing element, such as a spring 284, in the first chamber 272, is configured to apply a selected force to the piston 280 in order to cause it to move outward. Because the piston 280 is connected to the pad 250, moving the piston outward causes the pad 250 to extend from the surface 252 of the drill bit 200. In one aspect, the chambers 272 and 274 are in fluid communication with each other through a first fluid flow path or production line 282 and a second fluid flow path or flow line 286. A flow control device, such as a check valve 285 located on the fluid flow path 282, can be used to control the fluid flow rate from chamber 274 to chamber 272. Similarly, another device a flow control device, such as a check valve 287 located on the fluid flow path 286, can be used to control the flow rate of fluid 278 from chamber 272 to chamber 274. Flow control devices 285 and 287 can be configured on the surface to set flow rates in flow lines 282 and 286, respectively. In another aspect, these velocities can be constant or can be dynamically adjusted by the active device, for example, by controlling fluid flows between chambers using actively controlled valves. In certain embodiments of the invention, fluid flow is actively controlled by adjusting fluid properties using electro- or magnetorheological fluids and controllers. In other embodiments of the invention, piezoelectronic devices are used to control fluid flows. In one aspect, one or both of the flow control devices 285 and 287 may include a variable displacement device, such as a spring, to provide a constant flow rate from one chamber to another. The exchange of fluid flows at a constant speed between the chambers 272 and 274 provides a first constant speed for extending the piston 280 and a second constant speed for retracting the piston 280, and therefore corresponding constant speeds of extension and retraction of the pad 250. The size of the flow control lines 282 and 286 together with By adjusting their respective displacement devices 285 and 287, flow rates are determined from lines 282 and 286, respectively, and, consequently, the corresponding speed of the platform extension and retraction 250. In one aspect, the flow Naya line 282 and its corresponding flow control device 285 may be configured so that when the drill bit 250 is not used, i.e., the platform 250 is not affected by any external force, the biasing member 280 will raise pad 250 to the maximum extended position. In one aspect, flow control line 282 may be capable of relatively quickly or abruptly extending platform 250 with biasing member 280. During operation of a drill bit, for example while drilling a well, the load on the bit will cause an external force to act on platform 250. This external the force causes the pad 250 to exert an influence or pressure on the piston 280 and, thus, on the biasing element 284.

In one aspect, the fluid flow path 286 may be configured to provide a relatively slow fluid flow rate from chamber 272 to chamber or reservoir 274, which causes a relatively slow retraction of the site. As an example, the extension speed of the pad 250 can be set so that the pad 250 extends from a fully retracted position to a fully extended position within a few seconds and retracts from a fully extended position to a fully retracted position for one or several minutes or more (e.g. , within 2-5 minutes). It should be noted that any suitable speed for extending and retracting the pad 250 can be set. In one aspect, the device 260 is a passive device that adjusts the extension and retraction of the pad based on or in response to force or pressure on the pad 250. In an example embodiment of the pad 250 are wear resistant elements, such as cutters, rounded elements, rolling contact elements or other elements that reduce friction against rocks. In certain embodiments, the pads 250 are located directly on the front and in the same grooves as the cutters 239a, 238b. In an example embodiment, the device 260 is oriented with an inclination in the direction opposite to the direction of rotation to minimize the tangential component of the frictional force acting on the piston 280. In certain embodiments of the invention, the device 260 is located inside the blades 234a, 234b, etc. and is supported by the body of the bit 201 with an interference fit near the front face 232a of the bit 200 and a threaded tip or retainer, or a snap ring near the upper end of the side portion 234a, 234b.

In FIG. 3, an alternative speed control device 300 is illustrated. Device 300 includes a fluid chamber 370 divided by a dual-action piston 380 into a first chamber 372 and a second chamber or reservoir 374. The chambers 372 and 374 are filled with hydraulic fluid 378. The first production line 382 and associated flow control device 385 allow fluid 378 to flow from chamber 374 to chamber 372 at a first flow rate, and flow line 386 and associated flow control device 387 allow fluid 378 to flow from chamber 372 to chamber 374 to a second speed rosti. The piston 380 is connected to a force transmitting device 390 comprising a piston 392 and a chamber 394. The chamber 394 comprises a hydraulic fluid 395 that is in fluid communication with the pad 350. In one aspect, the pad 350 can be located in the chamber 352 that is in fluid communication with the fluid 395 in the chamber 394. When the biasing device 384 moves the piston 380 outward, it moves the piston 392 outward and into the chamber 394. The piston 392 displaces the fluid 395 from the chamber 394 into the chamber 352, which leads to the extension of the pad 350. When a force is applied to the pad 350, she pushes fluid out of chamber 352 into chamber 394, resulting in the application of force to piston 380. The speed of piston 380 is controlled by fluid flow through flow line 386 and flow control device 387. In the specific configuration illustrated in FIG. 3, the speed control device 300 is not directly connected to the platform 350, thereby isolating the device 300 from the platform 350 and positioning it at any desired location on the drill bit, as described in reference to FIG. 5-6. In another aspect, the pad 350 may be directly connected to the cutter 399, or the end of the pad 350 may be in the form of a cutter. In this configuration, cutter 399 acts both as a cutter and as a platform with the possibility of extension and retraction.

In FIG. 4 illustrates a conventional speed control device 400 configured to operate with more than one site, such as sites 350a, 350b ... 350n. The speed control device 400 is the same as illustrated and described in FIG. 2, except that it is illustrated by applying force to the pads 350a, 350b ... 350n through an intermediate device 390, as illustrated and described with reference to FIG. 3. In the embodiment of FIG. 4, each of the sites 350a, 350b ... 350n is housed in separate chambers 352a, 352b ... 352n, respectively. The fluid 395 from the chamber 394 is supplied to all chambers, which leads to the automatic and simultaneous extension and retraction of each of the sites 350a, 350b ... 350n based on external forces acting on each such site during drilling. In aspects, the speed control device 400 may comprise a suitable pressure compensator 499 for use in the well. Similarly, any of the speed controllers manufactured in accordance with any of the embodiments of the invention may use a suitable pressure compensator.

In FIG. 5 is an isometric view of a drill bit 500 in which a speed control device 560 is located in a section of a crown 530 of a drill bit 500. The speed control device 560 is the same as in FIG. 2, but is connected to the platform 550 by means of a hydraulic connection 540 and a hydraulic conduit 542. A speed control device 560 is illustrated located in the recess 580 with accessibility from the outer surface 582 of the crown section 530. The platform 550 is illustrated at the location of the front face section 552 on the front face of the drill bit 532, while the hydraulic connection 540 is shown located on the crown 530 between the pad 550 and the speed control device 560. It should be noted that the control device speed 560 can be located at any desired location on the drill bit, including neck 520 and neck section 510, and hydraulic line 542 can extend in any desired way from speed control device 560 to platform 550. This configuration provides flexibility in positioning the device speed control almost anywhere on the drill bit.

In FIG. 6 is an isometric view of a drill bit 600 in which a speed control device 660 is located in a flush groove 625 of a drill bit 600. In the specific configuration of the drill bit of FIG. 6, a hydraulic connection 640 is located near the speed control device 660. A hydraulic line 670 passes from the hydraulic connection 640 to the platform 650 through the neck 620 and the crown 630 of the drill bit 600. During drilling, the fluid passes through channel 625. To allow free passage of fluid through channel 625 speed controller 660 may be equipped with a through hole or channel 655, and hydraulic coupler 640 may be equipped with channel 645.

In FIG. 7, a drill bit 700 is illustrated in which an integrated platform and speed control device 750 is located on the outer surface of the drill bit 700. In one aspect, the device 750 includes a speed control device 760 connected to the platform 755. In one aspect, the device 750 is a sealed unit that can be attached to any outer surface of drill bit 700. The speed control device 760 may be the same or different from the speed control devices described in the present cumene with reference to FIG. 2-6. In the specific embodiment of FIG. 7, the pad is illustrated with a bit 720 of a drill bit 700 attached to a side portion 720a. A device 750 may be attached or placed at any other suitable location for the drill bit 700. Alternatively or as an addition to this, the device 750 may be integrated into the blade in such a way that the platform will extend in the desired direction from the drill bit.

In FIG. 8A, an integrated speed control device 800 is illustrated. In an example embodiment of the invention, the speed control devices 800 are separate standalone cartridges configured to accommodate chisel blades, such as those described previously, within the blades. In this embodiment, the speed control function is performed by a pressure control device, such as a multi-chamber outlet 899. FIG. 8B illustrates a multi-chamber outlet 899 with a plurality of outlet openings 898 providing a winding path for fluid 878 to flow between the upper chamber 872 and the lower chamber 874. In an example embodiment, the upper chamber 872 is subjected to higher pressure than the lower chamber 874. In certain embodiments of the invention, the lower chamber 874 is close to the pressure in the well. Accordingly, in an example embodiment, a multi-chamber outlet 899 controls the movement and pressure within the speed control device 800 in conjunction with the biasing member 884 by controlling the flow of fluid 878 therein. Accordingly, the speed of the pad 850 is effectively controlled by adjusting the properties of the outlet 899. In certain embodiments, the lower chamber 874 is pressure compensated. In an example embodiment of the invention, the lower chamber 874 is made with pressure compensation by pressure in the well to minimize the pressure drop across the fluid-oil seal 875 on the front face of the bit.

In FIG. 9, an integrated speed control device 900 is illustrated. In an example embodiment of the invention, the speed control devices 900 are separate standalone cartridges configured to accommodate chisel blades, such as those described previously, within the blades. In this embodiment, the speed control function is performed using a pressure control device, such as a high-precision clearance 999 between the piston 980 and the cylinder 994. A high-precision clearance 999 allows you to move a predetermined amount of fluid 978 between the upper chamber 972 and the lower chamber 974 at a certain pressure drop, effectively controlling the speed of the piston 980. In certain embodiments of the invention, the high-precision clearance 999 also plays the role of a high-pressure seal between the two chambers 972, 974. In certain embodiments, chambers 972, 974 respectively comprise a high pressure fluid and a low pressure fluid. In an example embodiment, the lower chamber 974 (low-pressure chamber) is configured to compensate for pressure in the well to minimize pressure drop across the fluid-oil seal (not illustrated) on the front face of the bit. In an example embodiment of the invention, pressure compensation is achieved through a bellows in communication with reservoir pressure in the well.

In FIG. 10 illustrates a drill bit 1000 with a speed regulator 1090 located on a bit connector 1091 of a drill bit 1000. In an example embodiment of the invention, the speed control device 1090 is hydraulically connected to multiple pistons 1080 through hydraulic channels 1092 configured to pass fluid 1078 through them to act in as a transmission mechanism 1056a. An advantage is provided that the central position of the speed control device 1090 provides more space for the speed control device 1090 and allows the use of multiple pistons 1080 and load balancing during operation of the drill bit. In certain embodiments of the invention, the pressure drop across the bit 1000 is used to create a downward force. In these embodiments of the invention, the low pressure chamber 1074 is compensated to provide the same pressure as the fluid pressure inside the bit, while the upper rod or chamber 1072 of the compensation piston 1080 is subjected to pressure inside the bit 1000, which creates a downward force. In certain embodiments of the invention, the additional transmission mechanism 1056b is in fluid or mechanical communication with the pad 1050.

In FIG. 11 illustrates a drill bit 1100 with a speed regulator 1190 located in the center of the drill bit 1100. In an example embodiment of the invention, the speed control device 1190 is located in the center and is mechanically or hydraulically connected to multiple sites 1150. An advantage is provided in that it allows reduce the peak pressure inside the speed controller 1190, as well as reduce the number of parts, since the platforms 1150 are driven centrally, as illustrated in Phi . 4.

In FIG. 12 illustrates a speed control device 1200 using a triple-wall cylinder 1298 with annular gaps 1299 between walls 1298a, 1298b, 1298c. In an example embodiment, the annular gap 1299 is a pressure control device, such as a high-precision gap for restricting fluid flow 1278 to control the movement of piston 1280. In an example embodiment, fluid flow 1278 moves through openings 1299a and 1299b to connect to both sides of piston 1280 In certain embodiments of the invention, the openings 1299a and 1299b have check valves to restrict the flow of fluid 1278. During operation, fluid 1278 is limited by a clearance 1299 to control Otoko fluid 1278, which leads to a controlled movement of the piston 1280. In certain embodiments, the invention uses pressure compensator 1297 to compensate for pressure in the lower chamber 1274 to the fluid pressure level in the well.

In FIG. 13 illustrates a speed control device 1300 with a compensation piston 1380. In an example embodiment of the invention, the double-acting piston 1380 with a predominantly equal rod size is exposed to both the upper chamber 1372 and the lower chamber 1374. In the example embodiment, both ends of the piston 1380 are subjected to pressure in the bottom so that the resulting force acting on the piston 1380 as a result of fluid pressure is close to zero. In certain embodiments of the invention, a hydraulic accumulator 1399 can be used with a compensation piston 1380 to adapt to changes in fluid volume due to changes in temperature, air inclusions, and leaks. In certain embodiments of the invention, biasing member 1378 is used to provide downward force. An advantage is provided that both chambers 1372, 1374 are compensated to minimize pressure drop between the speed control device 1300 and the wellbore.

In FIG. 14 illustrates a speed control device 1400 using a rotary fluid-oil seal 1496 when positioned within a drill bit (schematically illustrated as 1401). In an example embodiment, a cam 1492 is located outside the drill bit 1401, and rotational movement is transmitted through the shaft 1491 to the bit body via a rotary seal 1496. The rotational movement is converted into translational motion inside the bit body using a second cam 1493 and a pusher 1494 connected to the piston 1480 In certain embodiments of the invention, for example, when a shallow depth of cut is desired, the first cam 1492 leaves the connected adaptive element 1450 open. Since the outer the load acts on the first cam 1492, this load rotates the first cam 1492, and then the second cam 1493, which, in turn, causes the piston 1480 to retract (hide). When the external load is removed, the piston 1480 extends under the force exerted by the spring 1484 , and in turn turns the cams 1492, 1493 and leaves the adaptive elements 1450 open. Thus, the contact element 1450 extends (opens) and retracts (hides) at different speeds controlled by the profile of the cams 1492, 1493 and the characteristic and a biasing member in 1484.

In FIG. 15 illustrates a speed control device 1500 using a fixed pressure control device 1599. In an example embodiment of the invention, pressure control device 1599 is stationary with respect to a moving piston 1580. In an example embodiment of the invention, fluid pressure in well 1575 acts on a separator 1597 to compensate for reservoir pressure 1574. Fluid 1587 may flow between fluid chamber 1572 and reservoir 1574 through pressure control device 1599. In one aspect, chamber 1572 and reservoir p 1574 are in fluid communication with each other through a first fluid flow path or flow line 1582 and a second fluid flow path or flow line 1586. A flow control device, such as a check valve 1585 located on flow line 1582, can be used to control fluid flow rate from reservoir 1574 to chamber 1572. Similarly, another flow control device, such as a check valve 1587 located on flow line 1586, can be used to control the flow rate of fluid 1578 from chamber 1572 to reservoir 1574. Flow control devices 1585 and 1587 can be configured on the surface with the ability to set flow rates through flow lines 1582 and 1586, respectively. In certain embodiments of the invention, the pressure exerted by the fluid in the borehole 1575 biases the piston 1580 downward.

Thus, in one aspect, a drill bit is disclosed, comprising: a bit body; platform associated with the body of the bit; a speed control device attached to the platform configured to extend from the surface of the bit at the first speed and retract from the extended position to the retracted position at the second speed in response to external force acting on the platform, the speed control device comprising: a piston for applying force to the platform ; a biasing element configured to apply force to the piston to extend the platform at a first speed; fluid chamber associated with the piston; and a pressure control device for monitoring fluid pressure within the fluid chamber. In certain embodiments, the second speed is less than the first speed. In certain embodiments of the invention, the fluid chamber is divided by a piston into a first fluid chamber and a second fluid chamber. In certain embodiments of the invention, the pressure control device is a multi-chamber outlet. In certain embodiments of the invention, the pressure control device is a high-precision clearance located between the piston and the fluid chamber. In certain embodiments of the invention, the fluid chamber is a triple-wall cylinder having a first wall, a second wall, and a third wall, wherein at least one of the first wall, second wall, and third wall contains a high-precision clearance. In certain embodiments of the invention, the piston is a dual-action piston, wherein the fluid acting on the first side of the piston controls at least partially the first speed, and the fluid acting on the second side of the piston controls at least partially the second speed, and the pressure control device comprises at least one rod with a first end and a second end, and both the first end and the second end are subjected to pressure in the well. In certain embodiments of the invention, the speed control device comprises a drive coupled to a first side of the piston and a second side of the piston. In certain embodiments of the invention, the piston is a plurality of hydraulically connected pistons. In certain embodiments of the invention, the platform is a plurality of platforms configured to extend from the speed control device, the speed control device being located in the center. In certain embodiments of the invention, the speed control device is inclined in a direction opposite to the direction of rotation of the drill string. In certain embodiments of the invention, the speed control device is a stand-alone cartridge. In certain embodiments of the invention, the self-contained cartridge is coupled to the drill bit by interference fit or retainer.

In another aspect, a method for drilling wells is disclosed, comprising: providing a drill bit comprising a bit body, a pad associated with the bit body, and a speed control device; the introduction of the drill string into the formation, and the drill string has at its end a drill bit; selectively extending the platform from the surface of the bit at a first speed using a speed control device; selectively retracting from the extended position to the retracted position at a second speed in response to an external force exerted on the platform through the speed control device; a speed control device comprising: a piston for applying force to a site; a biasing element configured to apply force to the piston to extend the platform at a first speed; a fluid chamber associated with the piston; as well as controlling fluid pressure in the fluid chamber using a pressure control device; and drilling using a drill string. In certain embodiments, the second speed is less than the first speed. In certain embodiments of the invention, the fluid chamber is divided by a piston into a first fluid chamber and a second fluid chamber. In certain embodiments of the invention, the pressure control device is a multi-chamber outlet. In certain embodiments of the invention, the pressure control device is a high-precision clearance located between the piston and the fluid chamber. In certain embodiments of the invention, the fluid chamber is a triple-wall cylinder having a first wall, a second wall, and a third wall, wherein at least one of the first wall, second wall, and third wall contains a high-precision clearance. In certain embodiments of the invention, the piston is a dual-action piston, wherein the fluid acting on the first side of the piston controls at least partially the first speed, and the fluid acting on the second side of the piston controls at least partially the second speed, and the pressure control device comprises at least one rod with a first end and a second end, and both the first end and the second end are subjected to pressure in the well. In certain embodiments of the invention, the speed control device further comprises a drive coupled to the first side of the piston and the second side of the piston. In certain embodiments of the invention, the piston is a plurality of hydraulically connected pistons. In certain embodiments of the invention, the platform is a plurality of platforms configured to extend from the speed control device, the speed control device being located in the center.

In yet another aspect, a system for drilling wells is disclosed, comprising: a drill having a drill bit, which comprises: a bit body; platform associated with the body of the bit; a speed control device attached to the platform configured to extend from the surface of the bit at the first speed and retract from the extended position to the retracted position at the second speed in response to external force acting on the platform, the speed control device comprising: a piston for applying force to the platform ; a biasing element configured to apply force to the piston to extend the platform at a first speed; fluid chamber associated with the piston; and a pressure control device for monitoring fluid pressure within the fluid chamber. In certain embodiments, the second speed is less than the first speed. In certain embodiments of the invention, the fluid chamber is divided by a piston into a first fluid chamber and a second fluid chamber. In certain embodiments of the invention, the pressure control device is a multi-chamber outlet. In certain embodiments of the invention, the pressure control device is a high-precision clearance located between the piston and the fluid chamber.

In yet another aspect, a drill bit is disclosed, comprising: a bit body; platform associated with the body of the bit; a speed control device connected to the platform configured to extend from the surface of the bit at the first speed and retract from the extended position to the retracted position at the second speed in response to external force, the speed control device comprising: a piston for applying force to the platform; a biasing element configured to apply force to the piston to open the pad at a first speed; and a rotary device configured to apply force to the piston to conceal the site at a second speed. In certain embodiments, the second speed is less than the first speed.

The foregoing invention is directed to certain specific embodiments for ease of explanation. However, various changes and modifications of such embodiments of the invention will be apparent to those skilled in the art. It is intended that such changes and modifications within the scope and meaning of the appended claims be covered by the information disclosed herein.

Claims (33)

1. Downhole tool for rotary drilling, containing: tool body; a self-adjusting element, made with the possibility of extension and retraction, associated with the tool body and at least partially protruding above the surface of the tool body; a speed control device attached to the element, wherein the speed control device is configured to cause the element to extend outward relative to the tool body from the retracted position to the extended position at the first speed when there is no external force applied to the element, and the speed control device is configured to cause the element to be pulled inward relative to the tool body from an extended position to a retracted position at a second speed in response to an application to cop external force, wherein the second speed is different from the first speed, and speed control device comprises: a piston for applying force to the element; a biasing element configured to apply force to the piston to extend the element; fluid chamber associated with the piston; and pressure control device for controlling fluid pressure inside the fluid chamber. 2. The tool according to claim 1, characterized in that the second speed is less than the first speed. 3. The tool according to claim 1, characterized in that the fluid chamber is divided by a piston into a first fluid chamber and a second fluid chamber. 4. The tool according to claim 1, characterized in that the pressure control device is a multi-chamber outlet. 5. The tool according to claim 1, characterized in that the pressure control device comprises a gap between the piston and the fluid chamber. 6. The tool according to p. 5, characterized in that the fluid chamber contains a cylinder with a triple wall having a first wall, a second wall and a third wall, with at least one of the first wall, second wall and third wall having a gap. 7. The tool according to claim 1, characterized in that the piston comprises a double-acting piston, wherein the fluid acting on the first side of the piston controls at least partially the first speed, and the fluid acting on the second side of the piston controls at least at least partially, a second speed, and the pressure control device comprises at least one rod with a first end and a second end, and each of the first end and second end is subjected to pressure in the well. 8. The tool according to claim 7, further comprising a drive associated with the first side of the piston and the second side of the piston. 9. The tool according to claim 1, characterized in that the piston is one piston from a plurality of hydraulically connected pistons. 10. The tool according to claim 1, characterized in that the element is a pad or cutting element. 11. The tool according to claim 1, characterized in that the speed control device is located at an angle with respect to the direction of the expected rotation of the drilling tool to reduce the tangential component of the friction force (if any) that the piston collides with. 12. The tool according to claim 1, characterized in that the speed control device is a stand-alone cartridge. 13. The tool according to p. 12, characterized in that the stand-alone cartridge is held inside the drilling tool due to fit with an interference fit or retainer. 14. A method of drilling a well, comprising: embedding the drilling tool in the drill string, and such a drilling tool comprises a tool body, a self-adjusting element configured to extend and retract associated with the tool body and at least partially protruding above the surface of the tool body, and also a speed control device, wherein the control device contains a piston for applying a force to the element, a biasing element configured to apply force to the piston in the direction of the element, fluid th chamber associated with the piston, and a pressure control device for controlling the fluid pressure within the fluid chamber; the introduction of the drill string into the reservoir; the implementation of the outward extension of the element relative to the tool body from the retracted position to the extended position at the first speed controlled by the speed control device in the absence of application of an external force to the element; the implementation of the retraction of the element from the extended position to the retracted position at a second speed controlled by the speed control device in response to the application of an external force to the element by the formation, the second speed being different from the first speed; monitoring fluid pressure inside the fluid chamber by means of a pressure control device and drilling a borehole using a drill string. 15. The method according to p. 14, further comprising reducing the vibration of the drill string using a self-regulating element made with the possibility of extension and retraction. 16. The method of claim 14, further comprising adjusting the maneuverability of the drilling tool using a self-adjusting member configured to extend and retract. 17. The method of claim 14, wherein the second speed is less than the first speed. 18. The method according to p. 14, characterized in that the fluid chamber is divided by a piston into a first fluid chamber and a second fluid chamber. 19. The method according to p. 14, characterized in that the pressure control device is a multi-chamber outlet. 20. The method according to p. 14, characterized in that the piston is one piston from a plurality of hydraulically connected pistons.

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