RU2574429C2 - Valves of bottom-hole assembly and method for selective actuation of motor - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: group of inventions is refered to valves used for well drilling, bottom-hole assemblies and methods for selective actuation of downhole motor. The valve used for drilling of wells comprises a cylinder with inner space of circular cross-section, inlet opening, outlet opening and bypass opening, the first disc with orifice hole mounted in the cylinder so that the disc is rotatable, and the second disc with orifice hole mounted in the cylinder so that this disc is rotatable and pressed towards the first disc for the purpose of selective formation of sealing. The second disc is coupled to the motor rotor, while outlet opening is connected to the motor in order to supply fluid to the motor during its operation.

EFFECT: improved reliability and accuracy of control for the downhole motor operation.

18 cl, 5 dwg

Description

BACKGROUND OF THE INVENTION

Downhole turbine engines are powerful sources of energy used in drilling operations to rotate a drill bit, generate electricity, etc. The speed and torque created by the downhole turbine engine depend on its design and the supply of drilling fluid (drilling mud) to the downhole turbine engine. These parameters are controlled from the ground equipment of the well, adjusting the flow rate and pressure of the drilling fluid and adjusting the axial load on the bit. The accuracy of the control using these techniques is unsatisfactory. The engines may stall and their speed may vary due to load and movement of the drill string. Accordingly, there is a need to create devices and methods for more reliable and accurate control of the operation of a downhole turbine engine.

SUMMARY OF THE INVENTION

The objects of the present invention are valves, bottom-hole assemblies and methods for selectively actuating an engine.

In one aspect, a valve is provided comprising a cylinder having an inner space with a circular cross section, an inlet, an outlet, a bypass hole, a first disk rotatably disposed in the cylinder, and a second disk rotatably disposed in the cylinder and pressed against the first drive for selective formation of seals. The first disk and the second disk have a throttle hole.

The valve may have various embodiments. In one embodiment, the cylinder forms a proximal end and a distal end, an inlet and a bypass are located near the disks and the outlet is located at a distance from the disks. Disks may have a substantially circular profile. The throttle bore may be limited by the circular profile of the discs. In some embodiments, the throttle aperture has a substantially sectorial shape.

The first disk may be connected to the first spindle, and the second disk may be connected to the second spindle. Disks can be compressed together with spindles. Discs can be compressed together with one or more springs. Discs can be compressed together using one or more bearings.

Discs may include wear resistant material. The first disk may be connected to the control unit. The second disk may be connected to the rotor in the engine. The outlet may communicate with the engine. The inlet may communicate with the interior of the drill string. The bypass hole may communicate with the inner cavity of the drill string.

In another aspect, a bottom hole assembly is provided comprising a motor including a rotor and a stator, a valve including a cylinder having an inner space with a circular cross-section, an inlet, an outlet, an overflow hole, a first rotatably arranged disk in the cylinder and having a throttle aperture, and a second disk rotatably disposed in the cylinder, pressed against the first disk to selectively form a seal and having a throttle bore and a control unit phenomena. The first disk is connected to the control unit. The second disk is connected to the rotor. The outlet is communicated with the stator.

The bottom of the drill string may have various options for implementation. In one embodiment, the inlet is in fluid communication with the source. The source of fluid may be the interior cavity of the bottom of the drill string. The bypass hole may communicate with the internal cavity.

In another aspect of the invention, a method for selectively actuating an engine including a rotor and a stator is provided. The method comprises creating a valve including a cylinder having an inner space with a circular cross-section, an inlet, an outlet, a bypass hole, a first disk rotatably disposed in the cylinder and having a throttle aperture, and a second disk rotatably disposed in cylinder pressed against the first disk to selectively form a seal and having a throttle bore, creating a control unit connected to the first disk, and selectively actuating the bl Single control to rotate the first disc to the desired position for selectively supplying fluid through the throttle opening and the engine. The second disk is connected to the rotor. The outlet is in communication with the engine.

Description of drawings

For a more complete understanding of the nature and objectives of the present invention, the following is a detailed description with reference to the attached drawings. In the accompanying drawings, the same positions denote the corresponding parts in all figures. The drawings show the following.

1 shows a well site system in which the present invention can be used.

2A and 2B show a cross section of a mechanical seal valve according to one embodiment of the invention.

3A-3D illustrate disk interaction in a cylinder according to one embodiment of the invention.

4 is a cross-sectional view of a bottom assembly of a drill string including a downhole motor and valve according to one embodiment of the invention.

5 shows a method for selectively driving an engine according to one embodiment of the invention.

DETAILED DESCRIPTION OF THE INVENTION

Objects of the invention are valves, bottom-hole assemblies, and methods for selectively actuating an engine. Various embodiments of the invention may be used in well site systems.

Rig site system

1 shows a well site system on which the present invention can be used. The drilling site may be land or offshore. In this embodiment of the system, the wellbore 11 is made in subterranean formations using rotary drilling in a well-known manner. Directional drilling can also be used in embodiments of the invention, as described later in this document.

The drill string 12 is suspended in the wellbore 11 and has a bottom hole assembly (BHA) layout 100 that includes a drill bit 105 at its lower end. The ground part of the system includes a base and tower arrangement 10 mounted above the wellbore 11, and including a rotor 16, a drill pipe 17, a hook 18 and a swivel 19. The drill string 12 rotates the rotor 16, driven by means that are not shown and connected to the drill pipe 17 at the upper end of the drill string. The drill string 12 is suspended on a hook 18 attached to a tackle block (also not shown) through a drill pipe 17 and a swivel 19, which allows the drill string to rotate relative to the hook. It is known that an alternative top drive system can be used.

In this embodiment, the surface system further includes drilling fluid or flushing fluid 26 located in a reservoir 27 at the drilling site. The pump 29 feeds the drilling fluid 26 into the drill string 12 through the hole in the swivel 19, causing the drilling fluid to move downward through the drill string 12, as shown by arrow 8. The drilling fluid exits the drill string 12 through the holes in the drill bit 105 and then circulates upward through the zone annular space between the outer surface of the drill string and the wall of the borehole in the direction shown by arrows 9. In this well-known method, the drilling fluid lubricates the drill bit 105 and carries to the surface Drill the rock when returning to the tank 27 for re-circulation.

The bottom hole assembly 100 of the embodiment shown includes a logging while drilling module 120, a while measuring module 130, a rotary steering system and an engine, and a drill bit 105.

The logging module 120 during drilling is housed in a known special weighted drill pipe and may contain one or many known logging tools. It should also be understood that several logging modules during drilling and / or measurements during drilling can be used, for example, as represented by 120A. References to module 120 may alternatively also mean position module 120A. The logging module during drilling has the ability to measure, process and store information, as well as communicate with ground equipment. In the present embodiment, the logging module while drilling includes a pressure measuring device.

The measurement module 130 during drilling is also located in a known special weighted drill pipe and may contain one or more devices for measuring the characteristics of the drill string and drill bit. The measurement tool while drilling further includes a device (not shown) for generating electricity for the downhole system. Such a device may typically include a downhole turbine generator (also known as a “downhole turbine engine”) driven by the mud stream, it being understood that other power systems and / or batteries may be used. In the present embodiment, the measurement module during drilling includes one or more of the following measuring devices: an axial load measuring device for a bit, a torque measuring device, a vibration measuring device, an impact load measuring device, a sticking and slipping measuring device, an azimuth measuring device, and inclinometer.

In particular, it is preferable to use the system in combination with control of the direction of drilling or "directional drilling." In this embodiment, a rotary controlled drilling subsystem 150 is created (FIG. 1). Directional drilling is the deliberate deviation of the wellbore from the natural trajectory. In other words, directional drilling is controlling the direction of the drill string so that the string moves in the desired direction.

Directional drilling is, for example, preferable in offshore drilling, as it enables the drilling of multiple wells from one platform. Directional drilling also provides horizontal drilling through the reservoir. Horizontal drilling ensures the intersection of the reservoir with a segment of a larger length of the wellbore, which increases the flow rate of the well.

A directional drilling system can also be used in vertical drilling. Often, the drill bit deviates from the specified direction of the projected drilling path due to the unpredictable nature of the penetration layers or changes in the forces acting on the drill bit. When such a deviation occurs, the directional drilling system can be used to bring the drill bit back to the desired course.

A known method of directional drilling involves the use of rotary controlled systems. In these systems, the drill string is rotated from the surface, and downhole devices provide drilling with the drill bit in the desired direction. Rotation of the drill string significantly reduces the possibility of sticking of the drill string or stick during drilling.

Rotary guided systems for drilling directional boreholes in a geological environment can generally be classified as systems with bit direction or “bit deviation”.

In a system with a direction of the bit, the axis of rotation of the drill bit deviates from the local axis of the layout of the bottom of the drill string in the general direction of the new shaft. Posting the trunk is performed according to the usual three-point geometry formed by the upper and lower points of contact of the centralizer with rigid blades and a 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 provides the result of non-collinearity required to create a curve. There are many ways to achieve this condition, including fixed curvature at the point of assembly of the bottom of the drill string near the lower centralizer or bending the drive shaft of the drill bit between the upper and lower centralizer. In an idealized form, lateral rock failure is not required from the drill bit, since the axis of the bit continuously rotates in the direction of the curved shaft. Examples of rotary controlled positioning systems with bit positioning and methods for controlling them are described in US Patent Nos. 6394193, 6364034, 6244361, 6158529, 6092610, and 5113953 and US Patent Application Publications Nos. 2002/0011359 and 2001/0052428.

In a rotary controlled system with a deviation of the bit, there is usually no specially identified mechanism for deviating the axis of the bit from the local axis of the layout of the bottom of the drill string; instead, the desired noncollinearity condition is obtained by causing an eccentric force to be applied by the upper and / or lower centralizer or an offset in the preferred orientation relative to the direction of the barrel advance. There are also numerous ways that this can be achieved, including the use of non-rotating (relative to the barrel) eccentric centralizers (displacement-based approaches) and eccentric actuators that apply force to the drill bit for the necessary control of the direction of drilling. Directional control is also obtained by creating a non-collinearity condition between the drill bit and at least two other tangent points. In an idealized form, a lateral rock break is required from the drill bit to create a curved shaft. Examples of rotary controlled systems with bit deviation and methods of their operation are described in US patent No. 6089332, 5971085, 5803185, 5778992, 5706905, 5695015, 5685379, 5673763, 5603385, 5582259, 5553679, 5553678, 5520255 and 5265682.

Mechanical Seal Valves

On figa and 2B shows a cross section of the valve 200 with mechanical seal. The mechanical seal valve 200 includes a cylinder 202, a first disk 204a, and a second disk 204b.

The cylinder 202 has an inner zone 206 having a substantially circular cross section, a proximal end 208, and a distal end 210. The cylinder 202 also includes an inlet 212, an outlet 214, and an overflow opening 216. An inlet 212 and an overflow opening 216 are disposed. near the disk 204. The outlet 214 is located at a distance from the disk 204.

The disks 204 have a substantially circular profile that extends substantially along the circumferential wall of the cylinder 202. The disks 204 include one or more throttling holes 218 to allow fluid to pass through the valve 200 from the inlet 212 to the outlet 214 when the throttle holes 218 are aligned, as shown in FIG. 2B.

As shown in FIG. 2A, when the disks 204 are rotated to a position where the throttle openings 218 are not aligned, the fluid cannot pass through the throttle openings 218 to the outlet 214 and instead passes through the bypass hole 216.

As shown in FIG. 2B, when the disks 204 are rotated to a position where the throttle openings 218 are aligned, fluid can flow through the throttle openings 218 and exits the cylinder 202 through the outlet 214.

The throttle holes 218 may be limited by the circular profile of the disks 204, as shown in FIGS. 2A and 2B. Alternatively, throttle bores 218 may be sector-shaped, as shown in FIGS. 3A and 3B.

Disks 204 can be rotated by various devices including spindles 220.

Alternatively, discs 204 can be rotated by an electromagnetic clutch with an energy source mounted outside of cylinder 202.

The disks 204 are compressed together to form a substantially fluid tight seal when the throttle openings 218 are not in communication with each other. In some embodiments, discs 204 are compressed together by pressure applied to spindles 220. In other embodiments, discs 204 are compressed together by one or more springs 222 in cylinder 202 and / or one or more bearings or other geometric elements 224 in cylinder 202.

The cylinder 202 and the disks 204 are preferably constructed and / or coated with abrasion resistant materials that withstand friction during rotation of the disks 204 (for example, between the disks 204 and between other disks 204 and the cylinder 202), high temperatures and / or abrasive fluids (for example drilling mud). Suitable wear resistant materials include, but are not limited to, steel, "high speed steel", carbon steel, bronze, copper, iron, polycrystalline synthetic diamonds, hardfacing, ceramics, carbides, ceramic carbides, cermets, and the like. Suitable coatings are described, for example, in US Patent Application Publication No. 2007/0202350.

The first disk 204a may be coupled to a control unit 226 configured to control the actuation of the valve 200. In some embodiments, the control unit 226 holds the first disk 204a at a geostationary angle as the drill string rotates.

The control unit 226 can be mounted on a bearing, ensuring its free rotation around the axis of the layout of the bottom of the drill string. The control unit 226 according to some embodiments comprises measurement equipment, such as a three-axis accelerometer and / or magnetically sensitive sensors for measuring the inclination angle and azimuth of the bottom of the drill string. The control unit 226 may further communicate with sensors installed in the bottom hole assembly, so that the sensors can transmit formation characteristics or drilling dynamics data to the control unit. Formation characteristics may include information on adjacent geological formations collected by ultrasound or radionuclide imaging devices, such as those discussed in US Patent Application Publication No. 2007/0154341, which is incorporated herein by reference. These drilling dynamics may include vibration, acceleration, speed, and bottom hole assembly temperature measurements.

In some embodiments, the control unit 226 is programmed on the surface to follow the desired tilt angle and azimuthal direction. The progress of the bottom hole assembly can be measured using measurement systems while drilling and transmitted to the surface using pulsation sequences in the drilling fluid, using an acoustic or wireless transmission method, or using a wired connection. If the desired path is changed, new required instructions can be transmitted. Mud communication systems are described in US Patent Application Publication No. 2006/0131030, which is incorporated herein by reference. Suitable systems are available under the brand name POWERPULSE ™ from Schlumberger Technology Corporation of Sugar Land, Texas.

The second disk 204b may be coupled to the rotor of the downhole motor 228. The outlet 214 may be in communication with the engine such that a fluid flow from the outlet 214 rotates the rotor of the downhole motor 228 and rotates the second disk 204b. The downhole motor 228 can rotate a bit, a directional control device, and the like. in any necessary direction. For example, the downhole motor 228 may rotate the drill bit at the bottom of the drill string in a direction opposite to the direction of rotation of the drill string. The inlet 212 and the bypass 216 may communicate with the interior of the drill string to receive and release fluid.

Downhole motors are described in various publications, such as US Pat. Nos. 7442019, 7396220, 7192260, 7093401, 6827160, 6543554, 6543132, 6527512, 6173794, 5911284, 5221197, 5135059, 4909337, 4646856, and 2464011; U.S. Patent Publications No. 2009/0095528, 2008/0190669, and 2002/0122722, and William C. Lyons et al., Air & Gas Drilling Manual: Applications for Oil & Gas Recovery Wells & Geothermal Fluids Recovery Wells § 11.2 (3d ed . 2009); G. Robello Samuel, Downhole Drilling Tools: Theory & Practice for Engineers & Students 288-333 (2007); Standard Handbook of Petroleum & Natural Gas Engineering 4-276-4-299 (William C. Lyons & Gary J. Plisga eds. 2006); and 1 Yakov A. Gelfgat et al., Advanced Drilling Solutions: Lessons from the FSU 154-72 (2003).

On figa-3D shows the interaction of the disks 304 in the cylinder 302 (shown by dashed lines). The first disk 304a has a throttle hole in the form of a sector occupying 90 °, and the second disk 304b has a throttle hole in the form of a sector occupying 180 °.

3A, the first disk 304a is mounted so that its throttle bore is located in the upper right corner, and the second disk 304b is mounted so that its throttle bore is located in the upper half of cylinder 302 when viewed from the distal end 308.

3B, the second disc 304b is rotated 90 ° due to rotation of the downhole motor (not shown). The first disc 304a is also rotated 90 ° by a control unit (not shown) to maintain alignment of throttle openings to provide fluid to the downhole motor.

3C, the second disk 304b is further rotated 90 ° due to rotation of the downhole motor (not shown). The first disk 304a is held motionless by a control unit (not shown). At present, throttle openings are not aligned and fluid passes through the bypass hole, and not to the downhole motor.

The first disk 304a shown in FIG. 3D is rotated 90 ° by a control unit (not shown) to restore alignment with the second disk 304b, which remained stationary due to the cessation of flow through the valve 300. At present, the throttle openings are again aligned and the fluid can pass through the valve 300 downhole motor.

Bottom hole assembly

FIG. 4 shows a cross-section of a bottom hole assembly 400 including a downhole motor 402 and a valve 404. The downhole motor 402 includes a rotor 406 and a stator 408. Valve 404 includes a cylinder 410 with an inner zone 412 having essentially a circular cross section, an inlet 414, an outlet 416, and a bypass 418. The valve 404 also includes a first disk 420a and a second disk 420b located in the inner zone 412 of the cylinder 410. Each disk 420 has a throttle hole 422, and these holes can be combined to allow fluid (shown by solid arrows) to pass from the drilling cavity 424 columns 426 through inlet 414 throttle openings 422 and outlet 416 into downhole motor 402 to rotate rotor 406. Alternatively, when discs 420 are rotated so that throttle openings 422 are not aligned, fluid (shown in dotted arrows) passes from the inner cavity 424 of the drill string 426 through the inlet 414 and through the bypass 418 hole back into the inner cavity 424 of the drill string 426 before being discharged from below the drill string and / or through one or more throttling holes 428 located on the drill string 426. The first disk 420a can be controlled by the control unit 432, and the second disk 420b can be connected to the rotor 406, as discussed herein. The downhole motor 402 may be coupled to a drill bit, a directional control device, or the like. various connecting devices, including a universal joint 430, etc.

Method for selectively driving an engine

5, a method 500 for selectively driving an engine is shown. The motor includes a rotor and a stator.

In step S502, a valve is created. The valve may include a cylinder with an inner zone having a substantially circular cross section, an inlet, an outlet, and an overflow hole. The valve may also include a first disk and a second disk located in the inner zone of the cylinder. Each disc has a throttle opening, and these openings can be combined to allow fluid to enter the inlet, through the throttle openings, and out through the outlet. The second disk may be connected to the rotor, and the outlet may be in communication with the motor. The valve may be an embodiment of the valves described herein.

In step S504, a control unit is created. The control unit may be connected to the first disk.

In step S506, the control unit is selectively actuated to rotate the first disk to a desired position relative to the second disk to allow fluid to pass through the throttle openings and to the engine.

Link Included

All patents, published patent applications, and other sources disclosed herein are hereby incorporated by reference in their entirety.

Equivalents

Those of ordinary skill in the art should consider or be able to identify, using no more than routine tests, many of the equivalents of the specific embodiments of the invention described herein. Such equivalents are encompassed by the following claims.

Claims (18)

1. The valve used in drilling wells, containing a cylinder having an inner space with a circular cross-section, an inlet, an outlet and a bypass hole, a first disk rotatably placed in the cylinder and having a throttle hole, and a second disk located in the cylinder rotatably pressed against the first disk for selective formation of a seal and having a throttle hole, characterized in that the second disk is connected to the rotor in the engine, and the outlet is communicated a motor for supplying fluid to the engine for its operation. 2. The valve according to claim 1, wherein the cylinder has a proximal end and a distal end, an inlet and a bypass are located near the disks, and the outlet is located at a distance from the disks. 3. The valve of claim 1, wherein the disks have a substantially circular profile. 4. The valve according to claim 3, in which the throttle hole is limited by a circular profile of the discs. 5. The valve according to claim 3, in which the throttle hole has a substantially sectorial shape. 6. The valve of claim 1, wherein the first disk is connected to the first spindle and the second disk is connected to the second spindle. 7. The valve of claim 6, wherein the disks are compressed together by spindles. 8. The valve of claim 1, wherein the discs are compressed together by one or more springs. 9. The valve of claim 1, wherein the discs are compressed together by one or more bearings. 10. The valve of claim 1, wherein the disks include wear resistant material. 11. The valve of claim 1, wherein the first disk is connected to a control unit. 12. The valve according to claim 1, in which the inlet is in communication with the inner cavity of the drill string. 13. The valve according to claim 12, in which the bypass hole is in communication with the inner cavity of the drill string. 14. The layout of the bottom of the drill string containing an engine including a rotor and a stator, a valve including a cylinder having an inner space with a circular cross section, an inlet, an outlet, an overflow hole, a first disk rotatably disposed in the cylinder and having a throttle hole, and a second disk rotatably disposed in the cylinder, pressed against the first disk to selectively form a seal and having a throttle hole, and a control unit, the first drive connected to a control unit, a second disc connected to the rotor, and an outlet communicated with the stator. 15. The layout of the bottom of the drill string according to claim 14, in which the inlet is in communication with a source of fluid. 16. The bottom hole assembly of claim 15, wherein the fluid source is an interior cavity of the bottom hole assembly. 17. The layout of the bottom of the drill string according to claim 16, in which the bypass hole is communicated with the internal cavity. 18. A method for selectively actuating a downhole motor including a rotor and a stator for use in drilling wells, comprising the following steps:
creating a valve including a cylinder having an inner space with a circular cross section, an inlet, an outlet and a bypass hole, a first disk rotatably disposed in the cylinder and having a throttle opening, and a second disk rotatably disposed in the cylinder, pressed against the first disk for selective formation of a seal and having a throttle hole, the second disk being connected to the rotor, and the outlet opening in communication with the engine;
creating a control unit connected to the first disk; and
selectively actuating the control unit to rotate the first disk to the desired position to provide selective fluid supply through the throttle openings to the engine, thereby selectively driving the engine.

Images